bluuebunny/crossref_metadata_2025_split huggingface dataset:
3D Integrated Reservoir Modeling of a Structurally Complex Niger Delta Reservoir
Authors: Dike Francis , Osemoahu Omobude , Olatunji Idris , Mbursa Nayagawa , Amrasa Kefe , Aboaja Ugochukwu , Osho Rotimi 
Published: August 2012

Abstract
Accurate reservoir performance prediction m a structurally complex brown field is very important for generation of reliable production forecasts, location of possible by-passed oil estimation of reserves and optimal well/ reservoir management.
Reserves estimation is one of tire key functions of Petroleum Engineers and it requires an integrated approach for tellable estimates to be made. The traditional techniques include Decline curve analysis, Material balance. Volumetric. Analogues and Numerical Reservoir simulation.
Reservoir X is a structurally complex reservoir nr Field Y in the Niger Delta Basin. It came on stream in 1970 with 3 wells. Eight additional wells started production between 1972 and 1990. Five infill wells were drilled and completed between the years 2000-2005. However, due to operational and technical reasons (which are beyond the scope of this paper), 2 of these wells are yet to be put on production Over the years the reserves associated with these 2 wells have been estimated by analytical means (Volumetric and Material balance methods). However, there was the challenge of investigating the impact of fluid saturation changes around these wells, occasioned by the production fiom offset wells, on the reserves estimate obtained fiom material balance techniques These challenges necessitated the full field 3D integrated reservoir modeling
The reservoir contains 9 blocks in which 8 are densely faulted. The material balance analysis, being, at most, a onedimensional model, was deficient in robustly assessing the subsurface uncertainties which includes fault sealing potential and fluid contacts movement.
This paper discusses the techniques employed in building die static and dynamic models and shows a comparison of the reserves estimate results fiom analytical techniques versus 3D dynamic estimates.
Cleanup of Crude Oil Polluted Sites Using Arachis Hypogaea L. (Groundnut) and Biostimulants
Authors: Ekeh-Adegbotolu U. V , Ekeh O. M , Wegwu M. O. 
Published: August 2012

Abstract
Oil spill is a major problem in the Niger delta region of Nigeria. For every 10 spills that occur, there could be more than 5 affected lands. The increased role played by petroleum in Nigeria's economy has resulted in adverse environmental impact associated with oil exploration and exploitation. Some of these adversities have included soil deprivation and degradation. The soil quality for agricultural activities is altered by nutrient pauperisation, due to the presence or increase in oil and toxic metal concentration. Other impacts such as poor water quality affect surface and groundwater system as a result of oil spill and associated chemicals.
In recent times, the zero pollution campaign has been paramount in finding ways of combating oil pollution. The methods include chemical, thermal, bioremediation and phytoremediation. Some of these methods are very expensive and hazardous to the environment.
This paper examines the application of a common crop, Groundnut for the cleanup and remediation of crude oil polluted sites as a cost effective and profitable means of crude oil remediation. The research data shows the usefulness of planting groundnut for the cleanup and remediation of crude oil polluted sites. The research also investigates the level of crude oil cleanup through the use of biostimulants to aid the cleanup process.
The study shows about 73% oil clean up or extraction over a short period of 8 weeks compared to the 21 weeks life span of the plant. It also highlights the importance of biostimulants in crude oil remediation. This allows for enhanced remediation of crude oil polluted sites in a shorter time frame. This process is a pure and natural process for soil nutrient replenishment and enrichment. The harvested crop if not edible, could be used as a source for the production of biogas, an alternate energy.
Evaluation of Emulsion Treatment Using Different De-emulsifiers
Authors: Dosunmu A. , Otikiri A. E. , Fekete P. O. 
Published: August 2012

Abstract
Water in oil emulsion occurs at many stages in the production and treatment of crude oil. About two thirds of the produce of every new oil field exists in the form of water-in-oil emulsions. The emulsion stability results from the presence of interfacial barrier preventing coalescence of the dispersed water droplets; this is due to the present of polar components such as asphaltenes, resins, and wax and naphtenic acids in the crude oil. Therefore, before transporting or refining the oil, it is essential to separate the water for economic and operational reasons. In this research, three demulsifiers were used (Igepal co-720, Tween 40 and Tween 20) with the experimental work performed under room temperature. The results obtained with chemical demulsifier Igepal co-720 with Hydrophilic-Lipophilic Balance (HLB) of 14 were {31, 27, 24, 22 and 22%} of water separated from 5,4,3,2 and 1 ml concentration respectively at 60 to 120minutes optimum separation time. Similarly, from chemical demulsifier Tween 40 with HLB of 16 was {80, 74, 72, 70 and 55%) water separated from 5,4,3,2, and 1ml concentration respectively at 60 to 120minutes Optimum separation time. Finally, results obtained from chemical demulsifier Tween 20 with HLB of 17 were {95, 83, 67, 60 and 50%} respectively of water resolved from 5,4,3,2, and 1ml concentration at 60 to 120 optimum separation time. Comparing the three different chemical demulsifiers, it showed that Tween 20 has highest resolving power followed by Tween 40 and the least Igepal co-720. From this result it could be deduced that the higher HLB, the higher the separation of water in emulsion. In addition, a ranking of the demulsifiers used showed that highest capacity demulsifier was the demulsifier with highest HLB.
Smart Well Technology Application in Deepwater Field Development
Authors: Ekebafe Abraham , Ogan Asitonka 
Published: August 2012

Abstract
A Field development plan has been completed for a deepwater field located in gulf of guinea in water depth of around 1100 - 1400m offshore. The field is a confined turbidite channel system with some incised canyons and meandering channel complexes.
The stacked nature of some of the reservoirs lends itself to combinations of drainage points. This can be harnessed to - reduce the well count by accessing multiple sands in one wellbore, accelerate production, and improve ultimate recovery from better reservoir management and/or development of reserves which cannot bear the cost of a dedicated conventional well.
Smart well technology has been deployed in the field development plan to facilitate the realizations of these advantages and hence make the project economics more robust.
In applying the technology, an integrated approach has been adopted all through the reservoir modelling, well planning and completion design sessions to ensure feasibility from the onset. A multi-disciplinary team and tools were fully deployed to ensure maximum gain realized in the smart well technology application.
Based on the work done so far, the following justifies the appropriateness of the technology for the field:
Smart wells overall value is in reducing the well count and overall CAPEX whilst maintaining the UR – Well count reduction by ∼20%. Well and reservoir management (WRM) Facilitation – Additional 10% to be gained from WRM via smart field implementation of appropriate level of smartness.
This paper discusses the integrated approach and the tools that facilitated the process.
Well Performance Optimization Using Experimental Design Approach
Authors: Okenyi K. C , Emeka Omeke James 
Published: August 2012

Abstract
The production rate of a well is a functional relationship of system parameter, such as tubing internal diameter, gas/oil ratio (GOR), wellhead pressure, permeability, and skin among others. A sensitivity analysis is done by performance software to obtain the optimum production flow rate. Conventional method accomplished this by sequential optimization. Owing to its computationally expensive and time consuming nature, the need to determine the most profitable well design configuration while considering a number of system parameters simultaneously becomes very important. This procedure is called Multivariate optimization and of interest in this paper.
A preliminary investigation of factors affecting the well's production rate was done. An eleven variable Plackett-Burman design approach was used to screen the main effect of both reservoir and tubing flow variables. Pareto chart was plotted to highlight the heavy hitters.
A D-optimal design was also applied to minimize the volume of the confidence ellipsoid for the coefficient and provides the most accurate estimates of the model coefficients. A fully quadratic response surface was developed. Graphical analysis where used to show the optimum points as well as the optimum production rate. This model provides a tool for preliminary estimates of optimum production rate simultaneously with the effects of other variables.
Geocentrism and Multinational Strategy: Case Study of Upstream Oil and Gas Industry in Nigeria
Authors: Adedipe Adeleke 
Published: August 2012

ABSTRACT
The relationship between geocentrism and multinational strategy is non-definitive because of the difference of opinion amongst researchers however there is a paucity of existing work on the subject matter with respect to the upstream oil and gas industry. This current work is a case study approach to investigate the relationship between geocentrism and multinational strategy in two upstream oil and gas companies in Nigeria and the impact of the environmental dimensions (strategic, national and organizational) in the management of their subsidiaries.
This work is exploratory and utilizes existing constructs on multinational strategy, organizational design and index of geocentric orientation and data obtained from the survey of senior managers in the multinational companies. It reveals differences in the manner of correlation between geocentric orientation and the four corporate strategy variables or the four organization design variables for both companies. It indicates one of the two companies has an ethnocentric orientation, or can at best be classified as involved in enclave geocentrism, and thus signifying that a transnational company need not have a geocentric orientation. Furthermore it substantiates the impact of the strategic, organizational and national environmental dimensions in the management of foreign subsidiaries while indicating evidence of differences between espoused strategies and strategies-in-use in managing the Nigerian subsidiaries.
Concept of well design: NPT on drillers table – An Eco - Geomechanical Model for borehole stability management
Authors: Bassey Akong , Dosunmu Adewale , Alabi Tunde , Friday Otutu , Nnorom Grace 
Published: August 2012

Abstract
Mitigating drilling hazards ‘balancing drilling risks against the optimum well design while preparing for unplanned drilling events ‘has been a challenge to cost-effective well construction for decades. The pore pressure/formation fracture gradient balancing challenges mixed with the unexpected encounters with shallow flows, unstable formations, overpressure formations and depleted formations makes AFE (authorization for expenditures) goals dim. Excessive use of loss circulation pills and traditional contingency liners drive well costs up and jeopardize reaching total depth (TD) with an effective completion. A drilling hazard remediation solution could be as simple as using that planned contingency liner or using ddrrill-in casing to fight sloughing formations (McLean 1990). However, the use of conventional soolid expandable drilling liners can drive excessive risks into the well and even cause a costly sidetracking of the well on the drillers table. NPT in operations within areas of gulf of Guinea, gulf of Mexico and North sea have been successful due to absence of subsurface well integrity, lack of offset well information and economics. In view of this an Eco - geomechanical tool (GECDrill™) has been developed to handle the uncertainties created as a result of subsurface anomalies during well operations. Borehole drilling arises from the observation that an experienced driller can develop a good "feel" for the nature of formation being drilled. It should therefore be possible to establish an Eco - geomechanical tool (GECDrill™) to derive formation properties, subsurface geomechanical elements and cost indicators for economic evaluation through certain correlations. To minimize the NPT on drillers table, the Eco – geomechanical tool was developed based on realistic stress models coupled with linear elastic theorem and an economic risk assessment tool using a Monte Carlos bi-coupling strategy to evaluate the level and degree of NPT incurred while drilling in all fault scenarios.
A Simple Method to Estimate the Maximum Liquid Production Rate using Plunger Lift System in Wells
Authors: Bahadori Alireza 
Published: August 2012

Abstract
Plunger Lift is a cyclic method of artificial lift that uses a plunger to establish an interface between the liquid accumulated in the production tubing and the reservoir or annulus gas pressure that will be used to lift the fluid in wells. In this work, the maximum possible liquid production rate that plunger lift will tolerate for a given depth and tubing size has been placed on a quantitative basis by means of simple equations obtained from correlations of field data. The predictive tool developed in this study can be of immense practical value for petroleum engineers to have a quick check on the maximum possible liquid production rate that plunger lift will tolerate for a given well depth and tubing size at various wells without opting for any expensive field trials. In particular, petroleum and production engineers would find the proposed method to be user-friendly with transparent calculations involving no complex expressions.
Modern Magnetic Resonance Saturation Profile Data Accurately Quantify Fluid Volumes and Distribution in Tough Logging Conditions: Case Study from Niger Delta
Authors: Martey Amarquaye , Otevwemerhuere Joseph , Cavalleri Chiara 
Published: August 2012

Abstract
Future energy sources will come from their discovery by accepting more risk in exploration under tough drilling and logging conditions. In many fields in Nigeria, determination of producible oil and gas and in situ reserve volumes has proved too difficult for conventional, old vintage, logging suites. The complex mineralogy, presence of thin shale laminations and grain size variations within the sand bodies and very low and variable formation water salinity, require the use of advanced logging and conveyance technologies for accurate reservoir evaluation.
Advanced magnetic resonance wireline measurements provide a solution to evaluate reservoir quality and hydrocarbon systems potential. This technology is able to reveal a multitude of reservoir and wellbore properties supported by innovative signal processing and interpretation capabilities. This enables capturing essential information for multiple applications providing formation evaluation solutions unaffected by well deviations and borehole rugosity.
Continuous fluid characterization at multiple depths of investigation in a single logging pass from the advanced NMR tool resulted in correctly identifying the types and volumes of the various reservoir fluids and their contact levels.
The case study presented in the paper demonstrates the benefit of using advanced magnetic resonance in complex formation and in tough logging conditions where conventional measurements were inadequate. A major challenge in these reservoirs was the identification of the fluids contact, which was masked by poor resistivity contrast between oil and fresh formation water. In addition, the poor borehole conditions, severe enlargement and high rugosity, made it impracticable to successfully complete a planned wireline formation testing program.
The excellent data quality and reliability of the advanced magnetic resonance answer product despite the near wellbore damage and invasion effects proved that advanced magnetic resonance is a practical choice to provide accurate hydrocarbon volumes and in-situ fluid analysis to complement or fill the gaps in petrophysical and fluid sampling program in challenging complex and rugose borehole.
Modeling Approach for Niger-Delta Oil Formation Volume Factor Prediction Using Artificial Neural Network
Authors: Ikiensikimama S. S , Azubuike I. I. 
Published: August 2012

Abstract
Reservoir fluid properties are very important in reservoir engineering computations such as material balance calculations, well test analysis, reserve estimates, and numerical reservoir simulations. Ideally, this property should be obtained from actual measurements. Quite often, this measurement is either not available, or very costly to obtain. In such cases, empirically derived correlations are used in the prediction of this property. This work focuses on the use an artificial neural network (ANN) to address the inaccuracy of empirical correlations used for predicting oil formation volume factor. In this modeling approach 802 data set collected from the Niger Delta Region of Nigeria was used. The data set was randomly divided into three parts of which 60% was used for training, 20% for validation, and 20% for testing. Both quantitative and qualitative assessments were employed to evaluate the accuracy of the new Artificial Neural Network to the existing empirical correlations. The ANN model outperformed the existing empirical correlations by the statistical parameters used with a lowest rank of 0.855 and better performance plot.
Suitability of Local Demulsifier as an Emulsion Treating Agent in Oil and Gas Production
Authors: Oriji A. B , Appah Dulu 
Published: August 2012

Abstract
There is an increasing need to limit the use of chemical treating agents during oil and gas production and to search for safer and cost effective ones mainly due to environmental constraints. Therefore the use and performance of demulsifiers have to be improved from the application and cost as well as from the environmental issues. This means that new formulations must be less toxic and efficient compared to the general classical chemical families of demulsifiers which contain toxic molecules like phenol groups.
This paper is on the performance and the comparison of four chemical demulsifiers (local and foreign) on their demulsification of four crude oil emulsions of different asphaltene contents from different oil wells in the Niger Delta. The chemical families of these demulsifiers were screened with effective separation ability of different surfactants using classical "Bottle test". The Bottle test helped to determine the type of demulsifier that will most effectively break the emulsion of the crude samples. The basic aim of this screening was to compare and rank the efficiency of the various demulsifiers both local and foreign (V4404 of Nigeria, 92LTM174 of USA, EN/82/2 of France and DS 964 of Canada) in terms of percentage (%) volume of water that will be separated out of the samples. The results showed that the viscosity of the emulsions increased as the water content increased with an assumption that only oil and water were present. The nature of the emulsions were subject to changes, therefore no treatment method was conclusively generalized as best for every emulsion problem. Finally from the preliminary screening, the result also revealed that V4404 a local demulsifier exhibited very interesting performance and was also environmentally friendly compared to the imported ones.
Lithofacies Estimation by Multi-Resolution Graph-Based Clustering of Petrophysical Well Logs: Case Study of South Pars Gas Field of Iran
Authors: Aghchelou M. , Nabi-Bidhendi M. , Shahvar M. B. 
Published: August 2012

Abstract
South Pars gas field is the largest gas field of the world, located at the boundary between Iran and Qatar in the Persian Gulf in a distance of 100 kilometres from the southern shores of Iran. Its gas-in-place is estimated to be about 14.2 trillion square meters while the amount of its condensate-in-place might be around 18000 million barrels. South Pars gas field also has an oil layer containing about 6 billion barrels oil-in-place. Since South Pars field is a heterogeneous carbonate system, lithofacies characterization is the best solution for overcoming the problem of heterogeneity in determining the petrophysical properties of the reservoir rock, reservoir modeling and identifying producing zones, but coring which is the most robust method of lithofacies identification is very expensive, time consuming and is limited to few number of wells. Therefore this study is focused on determining the lithofacies of the understudy formations from available well logs. For this purpose multi-resolution graph-based clustering (MRGC) technique which is a dot-pattern recognition method based on non-parametric K-nearest neighbor and graph data representation is applied on sonic, density, neutron porosity and gamma ray well logs to define electrofacies similar to core-derived facies that are determined as twelve distinct ones. The cluster of the MRGC method is defined from model that has specific character associated with the group of lithofacies. Then, Kernel representative index is used to calculate the optimal number of clusters. Small facies groups are formed based on utilizing the neighboring index to determine a K-nearest neighbor attraction for each point. At last, final clusters are constructed by combining the small clusters which lead to identifying 12 facies of South Pars gas field from well logs by high accuracy. Method used in this study has obviated the need of extensive coring in the South pars field which caused saving large amounts of money and time.