bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated CMR, FMI and Facies Analyses to Assess Porosity Types and Distribution of the Middle Eocene Limestones- Case Study of Gas Reservoir, Pelagean Sea, Tunisia
Authors: Bey S.. , Ben Alaya S.. , Fakhfakh Ben Jemia H.. 
Published: September 2015

Abstract
Lower Reineche hydrocarbon-bearing limestones is subdivided into four different layers the first three ones (LRN1, LRN2, LRN3) belong to nummulite-rich unit and represent the main reservoir however the fourth layer (LRLs), which corresponds to an argillaceous limestones, is not considered as reservoir layer although its fair porosities. The sedimentological study based on CL description, USB, TS, and SEM analyses allowed the identification of eight facies. In the cored wells, the specified facies coupled to the FMI interpretation are used in order to recognize the specific response of each facies. Then the comparison of the FMI logs of the non-cored wells with those of the cored ones assists the prediction regarding facies and reservoir characteristics and helps to fill interpretive gaps when comprehensive formation evaluation data is not available. The CMR Logs show generally one modal T2 distribution illustrating the existence of only one fluid type except the LRN2 showing bimodal T2 distribution. In addition, this T2 signal is wide expressing a large pore size distribution (micro- to macroporosities). The sedimentological study proved the existence of matrix microporosity, an intergranular porosity between Nummulite tests and an intragranular porosity within Nummulites which is effective only when affected by microfractures (meso- to macroporosities). For Lower Reineche limestones, integration of sedimentological, RCA, FMI and CMR studies specified the different facies in addition to the porosity and permeability distribution in the reservoir. Nummulit biofabric and early diagenesis are the main factors that control the petrophysical characteristics of the Nummulit bearing limestones. The understanding of the heterogeneity and the distribution of the porosity and the permeability in this area is important for the reservoir modeling and the hydrocarbon (gas mainly) saturation.
Challenging Field Management of Thin Oil Rim Reservoir in Nile Delta of Egypt
Authors: Rabie Ahmed , Ghoneim Saad , Ali Mahmoud T. 
Published: September 2015

Abstract
West Dikirnis field is located in the Nile delta of Egypt. It contains a thin oil rim with a thick gas cap and strong water aquifer. It is considered the second oil discovery in the Nile delta after El Tamad Field (Operated by Petroceltic & El Mansoura Pet Co). The development of this thin oil rim is very challenging due to: 1) complexity of the fluid system (volatile oil, retrograde condensate gas cap gas), 2) complexity of the geology of the field (compartmentalization, fracturing, and rapid lithological variation), 3) high heterogeneity in reservoir properties (permeability ranges from 200 mD to 11 D), and 4) strong water drive.
This paper represents a case history of developing WD field. It presents a complete development plan of this thin oil rim and its rich gas cap and how to maximize liquid (oil & condensate and LPG) recovery through different stages by optimizing drilling/completion strategy, reservoir management, and production processing.
The production strategy of this field was put into phases. In the first phase, the thin oil rim reservoir was developed through vertical and deviated wells for the purpose of collecting geological and reservoir engineering data required for full field development. In this phase the simulation studies showed positive effects of recycling the produced gas into the reservoir gas cap for the purpose of maintaining the reservoir pressure and decreasing the liquid losses due to the expected retrograde condensation in the gas cap gas. This first phase has shown strong, but variable, aquifer effects on the production wells. It also showed a great deal of lithological variations within very short distances in the field. In the second phase, and to overcome the geological and aquifer heterogeneities, it was decided to develop the field with horizontal wells completed with ICD's (Inflow Control Devices). This type of development helped achieve the following: (i) overcome the geological complexity, and (ii) to keep the well away from the water table, (iii) control the water rise by gas cap gas recycling, and iv) normalize the water moving front towards the well bore by the use of ICD's. The studies have shown that the above strategy increases the oil recovery factor by about 50%.
In the third phase an LPG & Refrigeration project was constructed in order to maximize the liquid production from this field.
Currently, an EOR project is put in focus for further increasing of the liquid recovery from this field partly through vaporizing the remaining oil.
Case Studies of Formation Isolation Valves for ESP and Intelligent Completions in Multi-Lateral Wells and Horizontal Wells
Authors: Shafiq Muhammad , Arraour Ali Adlene 
Published: September 2015

AbstractThis paper describes case-studies of Formation Isolation Valve design, completion options, installations, well bore access for Intelligent Completions and successful replacement of electrical submersible pump (ESP). These completions are installed for production optimization in multilateral and horizontal wells. ESP completions has a long history in oil field and intelligent completions have been nearly stared 15years back.Isolation Valves have been installing for over 20 years and more than 2000 wells have been successfully completed. In few wells upper completions have been successfully recompleted with ESP. The technology has provided real value in these ESP wells and also in intelligent completions wells.There are several measures such replacement of underperforming ESP systems, sidetracks in more prolific zones and upsizing of the pumps have been taken. The formation isolation valves were used with ESP completion to protect reservoir formation from drilling and work over fluids during replacement of pump. This saves fluid cost, rig time, reduce rig cost, avoid formation damage and improve productivity. Few benefits are below: Allows multiple pump replacements without killing the wellIsolates formations without applying kill fluid to the formationReduces fluid losses during completion installationsImproves well productivity by preventing formation damageReduces costs associated with well interventionsESP systems with formation isolation valve are delivering the industry the solution to achieve production targets while protecting reservoir damage due to kill fluid during work over operations for pump replacement and at the same time allowing access to mother bore for stimulation and logging in ESP and Intelligent Completions.
An Experimental Investigation of Silica Nano Particles for Enhanced Oil Recovery Applications
Authors: Ragab Adel M. , Hannora Ahmed E. 
Published: September 2015

Abstract
By increasing worldwide energy demand and reducing reserves, enhanced oil recovery (EOR) from current fields has become more and more important. Moving from polymer to surfactant flooding, Chemical EOR has been considered an expensive method, and field applications have been decreased during the past two decades. Currently with the advent of nanotechnology, nanomaterials has been created and proposed to be used for EOR. Different nano materials with different sizes have been proposed. Among the various nano-material used for EOR applications, nano-silica with different sizes has been suggested.
In this paper, a ball milling attritor has been used to produce nano silica from white sand. By operating the attritor for a different time, different sized formed. Four different sizes have been created after 5, 10, 15, and 25 hours milling. The size and shape of the powder particles were examined using x-ray diffraction (XRD) and field emission-scanning electron microscope (FE-SEM) while their microanalysis was performed by energy dispersive system (EDS). The prepared nano particles were found 140, 122, 100, and 87 nm after 5, 10, 15, and 25 hours of milling respectively.
Several flooding scenarios have been tried to identify potential applications that will benefit upstream sector and oil recovery. A base run with water flooding (WF) was performed. The ultimate recovery factor by WF was found 67%. The ultimate recovery factors have been measured for these four nano materials and they are ranging from 65% to 77 %. To combine chemical EOR and nano materials, a mixture of nano material (87-nm) and polymer (xanthan gum) has been used as well, and its recovery factor is found 80%. The mechanisms of this development in the recovery has been explained.
This paper summarizes new findings from several different experimental runs which shows the effectiveness of the nano silica particles for improving oil recovery over the traditional methods. Ultimately, the knowledge gained from this work can be used to improve and narrow the range of nano-size applications for improving the recovery factors and proposed a roadmap for ongoing and future research.
Organic Geochemistry of the Paleozoic Source Rocks in the Chotts Basin, Southern Tunisia
Authors: Mohamed A. Belhaj , Saidi M.. , Soussi M.. 
Published: September 2015

Abstract
This paper describes a detailed geochemical evaluation of the Paleozoic source rocks in the Chotts basin- Southern Tunisia. Cutting samples collected from Middle Ordovician Azzel Formation (Fm), Late Silurian-Early Devonian FegaguiraFm and Permian ZoumitFm were analysed using Rock-Eval pyrolysis, GC and GC/MS techniques.
The FegaguiraFm is the principal petroleum source rock (SR) in the basin with Total Organic Carbon (TOC) values ranging from 1 to 20%. The Petroleum Potential (PP) and the Hydrogen Index (HI) values average 8 kg HC/t rock and 225 mg/g of TOC respectively indicate that the sediments have oil and gas generating potential. The terpanes series are dominated by the tricyclic and tetracyclic terpanes comparatively to hopanes with C23, C24 and C21 tricyclic terpane as prominent compounds. The diasterane contents are relatively high confirming the shaly character of the SR.
The Azzel shales has poor to moderate, occasionally good, potential for sourcing oil and gas with TOC and PP values varying from 0.80 to 4.49 % and from 0.68 to 9.20 kg of HC/t rock respectively. The HI values of 95–165 mg S2/g TOC and Tmax value of 435–448°C indicate mainly mature oil-prone kerogen. The biomarker features are characterized by high proportion of tricyclic terpanes that are dominated by C23 and C21 tricyclic terpanes. The hopanes fraction is dominated by C29 and C30 hopanes. The diasterane content are relatively high supporting the shaly character of the SR.
The ZoumitFm shows fair to excellent TOC ranging from 0.06 to 6.84% and fair to good PP (reaching 4.77 kg of HC/t of rock) and both HI and Tmax values indicate mainly immature oil-prone kerogen. The biomarker analysis reveals a low content of trictyclic terpanes relative to pentacyclic terpanes. The content of C29 and C30 hopane is relatively high. The diasteranes are present in moderate to high proportions and are less abundant than regular steranes. These biomarker features indicate a marine OM associated with marly to argillaceous limestone SR, deposited in suboxic, normal salinity depositional environment.
Mitigation of Stuck Pipe Challenges in HTHP conditions Using Acid Soluble Blend of Barite and Manganese Tetroxide as Weighting Materials for Drilling Fluids
Authors: Wagle Vikrant , Al-Yami Abdullah S. , AlAbdullatif Ziad , Bubshait Abdulaziz S. , AlSafran Ali 
Published: September 2015

Abstract
Horizontal wells drilled in the Marrat (lower Jurassic), Minjur and Jilh (upper and middle Triassic) formation in Saudi Arabia are known to present severe stuck-pipe challenges. Stuck pipe in a horizontal well is a problem that can result in loss of tools, non-productive time, sidetracks and loss of well thereby increasing the wellbore construction cost.
Thus to mitigate the problems arising due to stuck-pipe issues, a new drilling fluid was formulated using a combination of barite and manganese tetroxide (Mn3O4) as weighting agents. The use of such a combination as a weighting material in a drilling fluid provides both operational and monetary benefits.
Mn3O4 with a smaller particle size (D50=1 µm), spherical shape, and high specific gravity (4.95 g/cm3) makes it a good weighting material to reduce solids loading and settling compared to barite (SG= 4.20 and D50=20 µm). The fact that manganese tetroxide is also acid-soluble provides more operational benefits when a fluid with a combination of barite and Mn3O4 is used as weighting agent. In the event of a stuck-pipe incident during drilling, the use of acids or acid precursors would result in the dissolution of the Mn3O4 thereby resulting in a partial breakage of the manganese tetroxide-barite filter cake formed in a well during drilling. This partial breakage of the filter cake is expected to free the pipe thereby mitigating the problems associated with stuck pipe incidents. The use of a barite along with Mn3O4 would also result in a reduced fluid cost as compared to a fluid formulated with Mn3O4 alone as the weighting agent.
Thus, this paper showcases the benefits of using such a combination of barite and manganese tetroxide as weighting materials in 100pcf, 120pcf and 150pcf drilling fluids hot rolled at 250°F/300°F. The experimental work in this paper involves measuring rheological properties, thermal stability, HTHP filtration and static sagging resistance of the fluid at 250°F/300°F. The paper also describes the results of using different acid based filter-cake breaker fluids for the partial dissolution of manganese tetroxide based filter cake.
A blend of manganese tetroxide and barite provides increased sag resistance as compared to a drilling fluid formulated with barite alone as the weighting agent.
Utilizing of Waste Heat in Natural Gas Processing Plants for Efficiency Improvement by Using of Organic Rankine Cycle (ORC)
Authors: Hameed Ahmed Haridy , Zayed S.. 
Published: September 2015

Abstract
In recent years energy debates and emission regulations have pushed the whole world to explore alternative forms of energy, therefore it is important to explore innovative Measures to overcome the challenges of future fuel gas production shortage, future electric demand increase and GHG emission reduction. Industrial waste heat refers to energy that is generated in industrial process without being used, Waste heat recovery entails capturing and reusing the waste heat.
This paper introduces a case study to utilize the new ORC technology (Organic Rankine Cycle technology) on an existing El Gamil gas treatment plant, in order to recover the waste heat produced from no.4 turbo compressors exhaust with the aim of using it for process heating and power generation. A simulation model has been built up for two different types of engineering cycle, Different types of working fluids have been investigated for each cycle through different technical parameters in order to choose the best cycle and working fluid.
The simulation model shows that the regenerative cycle and cyclo-pentane as a working fluid is the most suitable selection for recovering the waste heat and convert it to process heating and power generation. The selected solution shows that the maximum power generated is 36 MW, the maximum cycle efficiency is 27% and the lowest working fluid volumetric flow rate is 7000 ACMH. On the other hand the economic study shows that the ORC technology is feasible, where the payback period is 4.5 year and IRR is 29%. The ORC technology saved fuel gas by 5,000,000 MMBTU/year, which environmentally decrease the CO2 emissions by 300,000 ton/year. And this enhances confidence towards applying the ORC technology in such gas treatment plants.
The Use of an Operational Filter Boosted Artificial Neural Network for Selection of Enhanced Oil Recovery Technique
Authors: Samuel Armacanqui J.. , Hassan Ahmed Mohamed 
Published: September 2015

Abstract
The variety of available EOR techniques requires an in-depth screening to select a viable method that matches well to the reservoir rock and fluid parameters and still remains economically attractive. In the present paper a Comprehensive Integrated EOR Workflow is proposed that starts with an Advanced EOR Screening Method. This is comprised of both a Neural Network Part and an Operational Module. While the First part uses proven data mining techniques the Operational Module considers the specific features of the screened EOR Method influencing the field implementation.
The Neural Network Part is based on an exhaustive review and selection of successfully deployed literature case. It uses the rock, fluid and other reservoir parameters to screen various EOR methods considering their technical-economical applicability. This Artificial Intelligence approach utilizes data mining techniques in the form of a hybrid system that makes use of a neural network as a screening tool and the genetic algorithm as an optimization tool to land into the optimum recommendation. The Operational Part enables to evaluate the implementation capability on the given field based on the specific requirements of the preselected EOR Method.
The system works its way through the literature data of successful EOR projects trying to detect patterns and learning from the data the relationship between these characteristics and the feasibility of applying each EOR technique mimicking the ability of the human mind to learn from previous experience. The system is a multi-layers neural network whereby the input layer is composed of seven key reservoir parameters (depth, temperature, porosity, permeability, initial oil saturation, oil gravity and in-situ oil viscosity) while the output layer is composed of the probability of success of the evaluated EOR methods (steam, CO2 miscible, hydro-carbon miscible, in-situ combustion, polymer flooding). The number of hidden layers and neurons are optimized using genetic algorithm for best matching of the training data set and accurate prediction of the testing set.
Comparing the system output with the actual applied EOR techniques in the field shows a reliable result with only a 5% miss-prediction of the total test fields. The Operational Module determines the deployment capabilities in the given reservoir considering the specific parameters of the pre-selected EOR Method, production-pressure history, Formation fluid flow properties and the actual field and well set up, thus providing an advanced EOR Screening.
Multilevel Markov Chain Monte Carlo (MLMCMC) For Uncertainty Quantification
Authors: Elsakout Doaa , Christie Mike , Lord Gabriel 
Published: September 2015

Abstract
Uncertainty quantification is an important task in reservoir simulation studies used for decision making. There have been many techniques proposed in the SPE literature for quantifying uncertainty, such as Markov chain Monte Carlo (MCMC).
MCMC is statistical method for sampling from an arbitrary probability distribution to quantifying uncertainty in reservoir simulation. The major difficulty in applying MCMC methods is high computational cost.
The purpose of this paper is to demonstrate the performance of a new technique – Multilevel Markov Chain Monte Carlo (MLMCMC) – for quantifying uncertainty in reservoir simulation with less computional cost compared to Standard MCMC.
MLMCMC algorithm is based on decomposing the desired results into a set of components calculated with different level of coarsening level. This technique demonstrated a speed up and provided a forecast with no significant loss in accuracy compared to Standard MCMC. It makes Monte Carlo estimation a feasible technique for uncertainty quanti?cation in reservoir simulation applications.
There are only a few applications of MLMCMC in the petroleum industry as it is a new technique. We show results for two fields. The first is Teal South in the Gulf of Mexico and the second is Scapa in a North Sea.
Application of Using Fuzzy Logic as an Artificial Intelligence Technique in the Screening Criteria of the EOR Technologies
Authors: Nageh Mohamed , El Ela Mahmoud Abu , El Tayeb El Sayed , Sayyouh Helmy 
Published: September 2015

Abstract
Screening criteria stage for the EOR applications is useful for many candidate reservoirs before expensive reservoir descriptions and economic evaluations are done. This paper presents the application of using fuzzy logic as an artificial intelligence technique in the screening criteria of the EOR technologies. EOR screening criteria have been developed based on field results. The database of 347 successful EOR projects worldwide is used to carry out statistical analysis which resulted in determination of four critical values (minimum, maximum, r1, r2) for each fluid and rock property.
The determined values identify the suitable range of the rock and fluid properties and the screening criteria for each EOR method. In addition, these ranges can rate the properties of any field under study from 0 to 1 (through fuzzy logic membership functions). The minimum and the maximum values represent the successful boundaries of the fluid or rock properties for the studied EOR method; while r1 and r2 values represent the ranges with maximum rating (best conditions) for the fluid or the rock properties.
Not all fields are amenable to EOR processes. Effective screening practices must be employed to identify suitable candidates. In the developed screening tool, there are 15 inputs representing EOR screening criteria of the reservoir rock and fluid properties including: API gravity, oil viscosity, reservoir depth, rock permeability, oil saturation, reservoir temperature, formation water salinity, net pay thickness, permeability variation coefficient (representing heterogeneity index), formation type, minimum miscibility pressure, initial reservoir pressure, current reservoir pressure, fracture pressure and an option showing if the reservoir is dip or not.
The developed screening tool is characterized by an easily and friendly interface with additional options comparing to the other existing software or expert systems. The proposed tool can be used to support the decision making during the critical technology selection phase. Such study is an original contribution to achieve successful EOR applications.
Economics of Organic Vs Inorganic Carrot Production in Nepal
Authors: Adhikari Raj Kumar 
Published: September 2015

During February-April 2008, a study was conducted to compare the yield and economics of organic and inorganic carrot production and its profit volume in Chitwan district of Nepal. Face to face interview method was used to collect the primary information from randomly selected organic and inorganic carrot producers. Among the cost components, per unit cost on female labor and organic fertilizer were found to be higher in organic production system where as higher per unit cost on seed, tillage operation and male labor were found in inorganic production system. Higher cost and higher revenue was found in inorganic production system but higher benefit cost ratio was found in organic production system. This revealed that adoption of organic carrot production system was economically profitable than inorganic production system. Key words: Benefit cost ratio; Carrot; Cost; Gross margin; Organic agricultureThe Journal of Agriculture and Environment Vol:10, Jun.2009 Page: 27-33