bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gas chimneys and their impact on gas migration, accumulation and de-risking of prospects, offshore Nile Delta - Central Sub Basin.
Authors: El Belasy A. M. , Talaat A.. , Matresu J.. 
Published: April 2013

Abstract
Baltim Concession is a large exploration/exploitation license located in the offshore Nile Delta, Egypt. The concession covers an area of 430 Km2 of the central portion of the present day Nile delta cone. High quality three dimensional (3D) seismic data, coupled with data from some wells drilled in the area, have highlighted the presence of some gas chimneys well recognizable started from pre-Messinian until the Plio-Pleistocene slope succession.
The geometry and architecture of the gas chimneys in Baltim area have been imaged by 3D seismic techniques, time section and a variety of attribute extractions, providing us with a high resolution definition of these features.
The main indicator for gas chimneys in seismic is an almost cylindrical shaped chaotic behavior of seismic signal, due to scattering of seismic energy by diffused gas through the cap rocks above the leaked reservoirs. The origin of gas chimneys has to be related to hydraulic fracturing by gas leaking through faults from deep accumulation where overpressure conditions have been generated by fast burial during the Plio-Pleistocene mega sequence deposition.
The petroleum system in Post-Messinian (Plio-Pleistocene) succession generated biogenic gas only, whereas the Pre-Messinian system proved to generate thermogenic gas and oil.
The role of gas chimney and associated structures as hydrocarbon migration pathways from the pre-Messinian kitchen section to the Post-Messinian reservoirs is testified by many DHI's within the Pliocene – Pleistocene reservoirs that are in contact with the boundaries of the gas chimneys.
In addition, geochemical analysis on gas samples from targets drilled in the Pliocene – Pleistocene indicates the presence of thermogenic gas clearly generated from pre-Messinian units.
From isotopic data, PVT samples and production data from gas fields discovered in Plio-Pleistocene succession evidenced that in many cases gas migrated from the pre-Messinian through high fracture zones related to gas chimneys activities in the studied area.
Applications of Nanotechnology in the Oil & Gas Industry: Latest Trends Worldwide & Future Challenges in Egypt
Authors: El-Diasty Abdelrahman Ibrahim , Ragab Adel M. 
Published: April 2013

AbstractNanotechnology has become the buzz word of the decade! The precise manipulation and control of matter at dimensions of (1-100) nanometers have revolutionized many industries including the Oil and Gas industry. Its broad impact on more than one discipline is making it of increasing interest to concerned parties.The Nanotechnology applications have pierced through different Petroleum disciplines from Exploration, to Reservoir, Drilling, Completion, Production and Processing & Refinery. For instance, Nano-sensors have been developed rapidly to enhance the resolution of the subsurface imaging leading to advanced field characterization techniques. Nanotechnology also strikes the stage of production enormously to enhance the oil recovery via molecular modification and manipulate the interfacial characteristics. Moreover, in a very similar fashion, it provides novel approaches to improved post production processes.Only very few publications were able to report the latest accomplishments in different Petroleum Engineering domains. This paper provides an overview of the latest Nano-technological solutions in the O&G industry and covers the recent research developments that have been carried out around the world and paves the way for many researchers and organizations who are interested in the integration of these technological advancements, to discover the challenges and the revolution that Nanotechnology is about to bring to O&G Industry in Egypt.Egypt's domestic demand for oil is increasing rapidly. Oil consumption has grown by more than 30% in the past ten years. Also, the hydrocarbon reserves in Egypt have witnessed an average increase of 5%/year over the past seven years, while the average recovery factor is still stuck at the 35%. Nanotechnology holds the key solution to this local production challenge as it helps increase the recovered Oil and decrease the cost of production by eliminating problems that occur throughout the field development operations.
A Road Map For Integrating a Giant Field: Case Study
Authors: Darhim M. Noureldien , Nassar Ibrahim , Salah Nabil , Mamdouh Mostafa , Merghany Ibrahim , Hassan Ahmed , Sobhy Mahmoud , Gamil Mohamed , Nabil Mohammed 
Published: April 2013

Abstract
El-Morgan Field was discovered in 1965 and is located offshore in the Gulf of Suez (GoS) approximately 160 miles south of Suez, Egypt. Peak Production was approximately 300,000 BOPD within only three years. El- Morgan is considered one of the giant fields since its STOOIP is estimated to be approximately 2.689 billion BO with an ultimate recoverable reserve around 1.439 billion BO. Over its history, more than 250 wells were drilled. Currently, 179 wells are operating (125 producers & 54 Injectors).
El-Morgan is considered highly sophisticated field due to reservoir heterogeneity (Kareem reservoir), moderate stratification, limited aquifer support, high bubble-point pressure, low-permeability layers and its friable sand. Due to the high bubble-point pressure and high initial-rate (Pi=2,990psi & PB=2,269psi), the bubble-point pressure was encountered early in the field resulted in using peripheral injection to support reservoir pressure. In addition the reservoir heterogeneity while injecting peripherally, it is believed that significant oil reserves were being bypassed and were potentially unrecoverable.
This paper presents an integrated approach to optimize the development for a complex field from both subsurface and operations views. It also shows studies conducted to maximize the asset value, explains how the development strategy have been revised over time, to augment oil ended by using an EOR method nowadays (BrightWaterTM). All of these studies are coupled to the economical calculations.
Managing giant fields with a significant potential is very important since each incremental 1% in RF will increase the ultimate recovery by tens of millions oil barrels. Also through this paper you will assure importance of certain reservoir evaluation tools and how you can optimize them to increase ultimate recovery factor. Paper is an excellent example for reservoir management that resulted in more than 52% primary RF.
High Resolution Saturation Analysis in Nile Delta Turbiditic Sands from Imaging Tool Resistivity and NMR in Oil-Based Mud
Authors: Salah A.. , Sabra M.. , Said M.. , Van Steenes M.. , Haddad E.. 
Published: April 2013

Abstract
Porosity, water saturation, and net-to-gross evaluation can be challenging in thinly bedded sands. The use of standard induction resistivity for formation evaluation can lead to the overestimation of water saturation. This work explores the following options to improve formation evaluation in these conditions: the use of high resolution density and nuclear magnetic resonance (NMR) data to improve porosity vertical resolution; the use of high-resolution resistivity from an oil-based-mud microresistivity imaging tool in improving the saturation computation (Sw); and the comparison of imaging tool resistivity-based sand count and NMR-based thin-bed fraction.
Using high-resolution porosity inputs from density and NMR provided a porosity curve with a better vertical resolution to match the high resolution resistivity from the imaging tool. It also identified additional productive thin beds compared to the standard resolution outputs and allowed computation of a high-resolution irreducible water saturation.
The induction-based Sw is strongly affected by shoulder bed effect and overestimates Sw by approximately 10 to 15%. The high-resolution curve from the imaging tool was used as an input into the Sw computation, which was made possible by shallow oil-based mud (OBM) invasion. This approach gave good results in beds thicker than 6 in., where Sw from the imaging tool matches the irreducible water saturation computed from NMR, giving 20 to 30% Sw.
A thin-bed fraction curve was computed from the NMR data. It shows a good match with the image-based high resolution- sand count and the image features, demonstrating that NMR and the imaging tool are equally able to identify and quantify thin beds, even though they have different vertical resolutions. This study showed that the microresistivity imaging tool and NMR are essential tools to characterize thinly bedded reservoirs.
The Use of Thermodynamic Reservoir Simulation to Investigate the Feasibility of Steam Flooding to Improve Oil Recovery in A Light Oil Reservoir
Authors: Al-Mudhafer Wathiq J. 
Published: April 2013

Abstract
Thermal oil recovery methods have been widely used not only in heavy oil reservoirs, but also in light oil reservoir with Waterflooding to improve oil recovery. The Steamflooding could be considered as an effective way to enhance the oil displacement especially in heterogeneous reservoirs The field, of 58-years of production history, is located in South of Iraq. It has 40 producing wells. There was an infinite active aquifer located at the east and west flanks. The strength of this aquifer from the west flank is much larger than its in the east flank because the reservoir permeability at the eastern boundaries is lower than as at the western one for all the layers; therefore, Twenty injection wells were drilled at the east flank to maintain the aquifer water approaching to the reservoir. The average surface area for this reservoir is 142 km2 and average formation depth of 10350 ft subsea with a maximum vertical oil column of 350 ft. Average porosity is 21%. The oil is 34°API with an average initial bubble point pressure of 2660 psia. Current reservoir pressure is approximately 4200 psia and the reservoir temperature is 210°F. In this study, a thermodynamic reservoir simulation has been adopted to investigate the competence of Steamflooding to improve oil recovery.
The objective of this work was to examine the feasibility of steam-injection processes, so a thermodynamical reservoir model (CMG-STARS) has been applied to demonstrate the effect of using steam injection as a heating agent to increase the sweep efficiency in this heterogeneous formation. The twenty injection wells have been converted to steam injection for twelve future prediction years. The process has demonstrated a considerable increase of the cumulative oil production. This result has been compared with the base scenario of water injection at the same injection rates of 10,000 STB/DAY per well. The water injection scenario has been done by CMG-IMEX. This incremental has been proved over most of the production wells that have distributed among the reservoir by showing a significant difference between the two cases.
Pressure Transient Data from Wireline Formation Testers : When and How to use it?
Authors: Ramaswami S.. , Hows M.. , Frese D.. , Dong C.. , Elshahawi H.. 
Published: April 2013

Abstract
The use of pressure transient data in the field of Formation Testing in efforts to describe productivity and permeability of reservoirs is considered mature technology, particularly when applied to data collected through production testing. The extension of this technique to data obtained using Wireline Formation Testers, where either a single probe or a straddle packer is used to propagate a pressure pulse into a reservoir, has been gaining momentum in the industry over the past decade, however the integration of these outputs with other measurements of rock and fluid data is not always straight forward. This paper presents different methods of using pressure transient data from Wireline Formation Testers such as quantitative permeability determination, identification of permeability discrepancies in homogenous clastic formations, upscaling of permeability in a complex stacked reservoir and comparison of Wireline Formation Tester and conventional well test derived permeabilities. Additionally, this paper highlights the challenges one faces while planning, acquiring and interpreting pressure transient data from Wireline Formation Testers, as well as the importance of real-time monitoring and control of data.
Comparative Study of Miscible Flooding in Compositional Graded Reservoir System
Authors: Hossain Mohammad Sohrab 
Published: April 2013

Abstract
Miscible gas injection in near critical oil or volatile oil reservoir improves the recovery due to interfacial tension effects and better microscopic displacement efficiency compared to immiscible water injection. In a graded undersaturated gas-oil fluid system, all fluids are initially first contact miscible with neighboring fluids throughout the reservoir if full- pressure maintenance is supported by injection process.
Smorbukk south is characterized as a compositionally graded gas condensate and volatile oil reservoir which lies near the critical region in the phase diagram. Compositional graded reservoir systems exhibit significant variation in the minimum miscible pressure (MMP). MMP variations with depth pose a challenge in selecting reservoir recovery technique to maximize the ultimate recovery.
This paper deals with different scenarios of miscible flooding and compares the results with immiscible flooding for a 3-D homogeneous reservoir system. Here, MMP, determined by different injection gases, can develop far below the saturation pressure. If the injectant is CO2 or sufficiently enriched with intermediate components, the condensing and vaporizing (C/V) mechanism was developed throughout the reservoir. Dipping effects and placement of injector -producer were studied here and was found that updip formation gives highest recovery. Various injection schemes (i.e. Separator Gas and CO2) were studied in miscible flooding scenarios. The results of gas alternating gas (GAG) were compared with the water alternating gas (WAG) method and GAG was found to be the best alternative.
Application of Relative Permeability Modifier for Sealant Diversion
Authors: Das Prasanta , Patil Prajakta , Agashe Snehalata 
Published: April 2013

Abstract
Organically crosslinked polymer (OCP) systems are well-known sealants used for water shutoff in conformance applications. However, in multizone treatments with significant differences in permeability, a diverter is essential to divert the sealant to shut off less-permeable zones. This paper investigates the use of a relative permeability modifier (RPM) as a diverter for the sealant. This solution is most effective at shutting off zones in cases where multiple water-bearing strata with different permeability are encountered. The sealant is proven to be effective, even at 400&deg;F.
Two sandpacks of different permeabilities were formulated. All diversion tests were performed at room temperature and without any backpressure. The RPM adsorbed to the high-permeability zone more than the low-permeability zone. Once adsorbed, the RPM hindered flow of the water-based sealant in the high-permeability zone and diverted it to the low-permeability zone. With higher flow rates, the effect of diversion was lower because more sealant in the low-permeability pack provided resistance for further penetration of the sealant. The RPM and sealant were mixed at different ratios and tested under high-pressure/high-temperature (HP/HT) conditions to observe the effect of mixing on the gelation time for the sealant. The effect of the RPM on gelation time for the sealant was insignificant, provided the polymer and crosslinker concentration of the sealant was constant.
RPMs have been widely applied to decrease the permeability to water in oil and gas wells. RPMs have also been used for acid diversion. The current study shows a new application of using RPMs as a diverter for sealants. This investigation will help increase the potential areas where multizone shutoff using a sealant treatment can be used.
Importance of Surveillance for Evaluating a New Reservoir Technology
Authors: Gobran Mahmoud H. , Kinawy Mahmoud M. , Bayoumi Radi S , Shahin Eman S 
Published: April 2013

Abstract
Morgan is the largest field in Gulf of Suez Egypt. It started production in April 1967. Morgan comprises two main reservoirs; Kareem and Belayim. Both reservoirs have weak aquifer support. Waterflooding was implemented in February 1974 to support the depleted reservoir energy and improve the sweep efficiency. Currently the field is mature and most of wells are producing with high water cut.
Kareem reservoir is heterogeneous and there is a high permeability variation between different layers and most of the injected water goes to high permeable layers.
BrightWater ™1 technology was developed to create baffles in the higher permeability layers to divert the injected water from previously swept layers to the un-swept zones which will improve the sweep efficiency.
North Morgan Kareem reservoir selected as a pilot for BrightWater deployment by treating five injectors which are impacting on ten producers. BrightWater uses a temperature activated cross-linked polymer carried with the injected water. Their distribution within the reservoir is proportion to the distribution of injected water. As the injected water moves away from the injection wells it is warmed by reservoir rocks. This rise in temperature causes the BrightWater chemical to activate and pop up to plug the higher permeability zones.
A complete evaluation for BrightWater is very important to define its value to be applied in other fields. Different surveillance tools were selected for Brightwater evaluation. These surveillance tools are summarized in: chemical Tracer detecting, well-testing, water cut measuring, pressure fall-off / step-rate testing, injectivity monitoring, and production / injection logging. All of these surveillance tools will be used in the three phases of BrightWater treatment; before popping, at popping, and after popping.
This paper will provide the BrigtWater technique principle for enhancing the sweep efficiency, the optimum surveillance tools to evaluate its impact and a real case history for North Morgan Kareem reservoir.
Integrated Reservoir Study of Mature Oil Field Resulted in Rejuvenation of an Abandoned Oil Reservoir to Add New Reserves and Production, GoS - Egypt
Authors: Gamal M. , Raafat M. , Thabt M. , Allam F. , Farouk H. 
Published: April 2013

Abstract
An integrated reservoir study was initiated to look for new opportunities in East Zeit field. The working team managed to construct the full field static and dynamic models. The main challenge during the history match phase was the high complexity of the structure, range of uncertainties, and the model running time. The team managed to understand unconventional reservoir aspects such as:
(1) The reservoir pressure was sharply decreases as production increases. Then, when the reservoir was abandoned as a depletion drive reservoir the pressure started to increase up to initial reservoir pressure without any intervention.
(2) The performance of few wells completed in the above mentioned reservoir was similar to the performance of wells in active water drive reservoirs.
Comprehensive work in the history match has been done to calibrate the model and explain the different phenomena in the field. The team explained the pressure increase in the depleted reservoir that it was due to the reactivation of faults which became non-sealing. This resulted in communication with another active water drive reservoir and natural miscibility process. The study recommended adding new off take point in the reservoir to confirm the concept. So, a new well was drilled and confirmed the study conclusion and managed to add more reserves and production in the rejuvenated reservoir after 12 years of shut in. Currently, constructing complete field development plan is in progress to maximize the recovery factor. Reservoir monitoring even after abandonment, especially with unconventional reservoir aspects, is very important to discover new opportunities and maximize the recovery. These opportunities should be managed through the integrated reservoir simulation studies to minimize the risk and cover the uncertainties.
Introduction
The East Zeit field (EZ) is situated in the southern Gulf of Suez (GoS) in about 240 ft of water (Fig.1). The oil accumulation in the field covers an approximately 27 km2 area. The field is composed laterally of two major fault blocks; the main fault block (MFB) and the east fault block (EFB). Moreover, each major fault block is sub-divided into smaller fault blocks which reflect the complexity of the highly faulted structure. Each major fault block is sub-divided vertically into three main reservoirs (Fig.2). The field was started production in 1985 through two platforms; the wells were flowing naturally in the past and currently some wells are producing by artificial lift and other wells are still flowing naturally.
Experimental Investigation of Low Salinity Hot Water Injection to Enhance the Recovery of Heavy Oil Reservoirs
Authors: Abass Elradi , Fahmi A.. 
Published: April 2013

AbstractMany laboratory core flood investigations have shown increased oil recovery is achieved by water flooding applying low salinity water, compared with injection of high salinity produced water or brine seawater. This work describes a sand pack flood test, designed to identify whether this process could be observed as additional mechanism to thermal drive mechanism as a new technique for heavy oil displacement. The core and sand pack flood test was schematically designed and conducted, to ensure that the results achieved concerning the salinity alteration under stabilized thermal displacement conditions, The result confirms a significant increase in oil recovery due to hot water low salinity injection. In all experiments done, approve the effect of low salinity as an additional to thermal recovery mechanism of heavy crude oil when applied to the residual oil after high salinity hot water flood. It would indicate that more than 25 percent additional oil would be recovered by low salinity as additional mechanism to hot water flooding. The studies have been conducted mainly for heavy oil from BAW Sudan oil field, under current reservoir conditions. Detailed benefits regarding to this technique is presented concerning to enhance oil recovery in BAW oil field.
Life Cycle Concept (LCC) in Waste Management in the O&G Offshore Exploration
Authors: Burlini Patricia Soares , Araruna José Tavares 
Published: April 2013

Abstract
There is a general belief that the oil industry has its activities incompatible with the concept of sustainable development. However, the development of humanity has been based on power consumption; much of them are provided by this industry. With the new exploratory oil &amp; gas (O&amp;G) frontier in Brazil, the pre-salt, it is possible to envision that the operating segment will be very present in the country, as well as their negative impacts to the environment and its tons of waste that will be generated. This paper seeks to promote reflection on the theme discussing the concept of life-cycle thinking (LCT). The application of life-cycle thinking to waste management brings a differential for long-term reduction of pollution, by facilitating the analysis of various aspects including the necessary infrastructure for managing legal matters (i.e., licensing) and logistics. LCT still promotes a better understanding for the general public, regulators, operators and companies providing services. It even allows companies in Brazil to be better prepared for the challenges related to the pollution generated by O&amp;G offshore exploration wastes.