bluuebunny/crossref_metadata_2025_split huggingface dataset:
Challenge in Managing and Optimizing Well Intervention Activity in Matured Oilfield: Approach Taken by Petronas Carigali Sdn Bhd in Accelerating the Capability and Efficiency
Authors: Hashim M Shahrizal 
Published: February 2010

Abstract
Well Intervention activity has become the main activity to ensure production sustainability and ensuring continuous reservoir management plan is properly captured especially for the low reserves field which striving to lower down the Unit Production Cost (UPC). In order to ensure higher job implementation efficiency and reduce the job failure percentage, proper field management has become the most crucial part. Inline with the aspiration, Petronas Carigali Sdn Bhd (PCSB) has established the new sections which are specifically looking for the improvement in well intervention activity which cater the HSE, field management, cost optimization and technical deliverability aspect.
From the total well intervention involved, slickline intervention are the main continuous activity in the region, however there is no specific do and don’t guideline available in the system. Besides, there is also number of coiled tubing and electric line intervention in the locations which possibly contribute to the failure during the job execution. By looking at those activities, the team has established the Technical Bulletin which contain the technical and HSE alert that was shared among all the PCSB fraternity. The bulletin was also shared to all related contractor to ensure its being followed by all parties. The team also focused on any non-routine and new technology or best practices activity implementation by continuously performed further analysis on any non-routine well intervention activity i.e. through tubing cement job, perforation, scale cleanup, etc. which contribute to the cost saving and production delivery to the organization. They internally established the useful Christmas tree health monitoring database in order to optimize the costs which are capable to track the current surface equipment condition inline with Well bore Risk Management (WRM) manual.
This paper discussed on the detailed function and contribution of the newly section development in PCSB that giving positive impact to the organization by showing their capability of optimizing the existing source in order to improve the well intervention efficiency.
Application of Chemical Tracers in IOR: A Case History
Authors: Asadi Mahmoud , Shook G. Michael 
Published: February 2010

Abstract
Secondary recovery is a process in which reservoir fluid is mobilized and moved from an injection well toward a production well. The success of this process greatly depends on the knowledge of reservoir continuity and uniformity, in terms of fluid transmissibility, and how much of the reservoir fluid volume can be contacted by the injection fluid. In any water/gas flood injection project, fluid channeling through mini-fractures, faults, and high permeability streaks results in problems such as poor reservoir sweep efficiency and low hydrocarbon recovery. Therefore, knowledge of direct communication between the injection and production wells as well as an understanding of formation heterogeneity can be of great help to overcome these problems. While techniques such as seismic, mapping geological deposition and reservoir simulation provide valuable information about the feasibility of secondary recovery projects, tracer testing is the only available method that provides valuable information on direct communication, flow-path, and formation heterogeneity across the injection and production wells. This paper presents a detailed review of chemical tracer applications in IOR with a supportive case history from a water-flood field. The paper also presents interpretation and discussion of the results on direct communication identification, formation heterogeneity evaluation, and swept pore volume calculation.
New Incubated Pseudomonas Aeruginosa Bacteria for Increasing Oil Recovery under Reservoir Conditions
Authors: Samir M.. , Abu El Ela M.. , El Marsafy S.. , El Tayeb S.. , Abdel Waly A.. , Sayyouh M. H. 
Published: February 2010

Abstract
Laboratory studies show the existence of some strains of bacteria in field crude oils and formation waters. This work is concerned with studying the effect of the reservoir conditions such as temperature, salinity and lithology on the indigenous bacterial activities. Such study is an original contribution to the knowledge of microbial enhanced oil recovery (MEOR).
Egyptian MEOR project at Cairo University succeeded to isolate a surfactant-producing microorganism "Pseudomonas Aeruginosa" from crude oil produced from an Egyptian oil field. Several displacement tests were conducted in sand pack model. A modified media was used to incubate and improve the growth rate, behavior and stimulation of Pseudomonas Aeruginosa.
The results obtained from the current work showed that Pseudomonas Aeruginosa succeeded to increase the oil recovery by 20%. Pseudomonas Aeruginosa becomes able to resist the effect of temperature up to 70°C and salinity up to 150,000 ppm, when a specific incubation technique is applied. There is no significant effect on the behavior of the bacteria in the presence of the Dolomite and Kailinite inside the reservoir. The value of the oil recovery factor in case of incubation of the bacteria outside the model is greater than its value in case of incubation inside the model by about 5%.
The results obtained are discussed and analyzed in terms of surface tension, hydrogen ion concentrations, viscosity, and conductivity of the effluent solutions.
Reservoir Pathway Identification in a Fractured Carbonate Heavy Oil Reservoir
Authors: Samir M.. , Hassan W.. , Omara M.. , Thabet E.. , Abugreen Y.. , Joshi S.. 
Published: February 2010

AbstractThe first production log in heavy oil in Egypt through y-tool, using a high capacity ESP pump, in an open hole completion was performed recently by Scimitar Production Company in Issaran heavy oil field. The objective of the job was to identify the source of water, evaluate the contributions from the different open hole zones and determine whether or not there is cross flow in this fractured heavy oil carbonate reservoir. These wells had originally not been completed with y-tool. Therefore a special y-tool with high capacity ESP was designed especially for Scimitar by Zenith to be able to log the wells under special dynamic conditions. This was the first application world wide of this y-tool, which was used as a temporary completion in the wells.Production logging (PL) was successfully carried out in 3 Issaran wells at different rates, to identify the high permeability (super-K) layers dominating production and calculate their pressure/PI. Likewise flow profiles were determined and high water producing layers identified. Shut in surveys were successful in detecting cross flowing layers. Calculated flow profile results matched well with surface measured rates.PL results had a significant effect upon the Issaran field development plan. Water was found to be produced from layers having resistivity up to 30 ohm-m. This led to an increase in the resistivity cutoff for hydrocarbon production and a reduction in water cut. Hydrocarbon producing zones were better identified and Scimitar decided to abandon open hole completions in future wells and go in for cased hole completions, in order both to control the water production as well as avoid breakthrough of injected steam.This paper describes the field and gives details on job planning, operations, results and way forward for field re-development.
Overview of Tight Gas Field Development in the Middle East and North Africa Region
Authors: Shehata Ahmed , Aly Ahmed , Ramsey Lee 
Published: February 2010

Abstract
As gas demand rises and operators turn to Unconventional gas reservoirs for new supplies, the need to optimize the capacity and recovery potential from this type of reservoir has risen. These Unconventional gas reservoirs represent a vast, long-term, global source of natural gas and have not been appraised in any systematic way. Unconventional gas resources—including tight sands constitute some of the largest components of remaining natural gas resources in the Middle East and North Africa. There is an emerging focus on tight gas reservoirs in the Middle East and North Africa to feed the growing energy needs in this region and save the oil from conventional resources for export and generation of hard currencies.
The greatest challenge for tight gas is to generate economic flow, so technical capabilities are needed for effective development and production of tight gas reserves, such as mineralology/geology, geomechanics, petrophysics, well engineering, and hydraulic fracturing.
During the last decade, 3-D seismic, horizontal drilling, and improved fracture stimulation have had significant impacts on tight gas production in many basins in the Middle East and North Africa.
In this paper we will present a documentation of all the tight gas reservoirs available in the Middle East and North Africa, the challenges of developing these difficult resources, the role of modern technologies in managing tight gas and improving recovery factors, and highlight the best strategies for field development in tight gas reservoirs to capitalize on the promising potential of these reservoirs.
The objective of this paper is to prepare data base to document all the tight gas reservoirs in the Middle East and North Africa and study the impact of technology on tight gas reservoir development in the emerging region.
Difficulties in Using Geostatistical Models in Reservoir Simulation
Authors: Rasouli V.. , Tokhmechi B.. 
Published: February 2010

Abstract
Number of estimators and simulators is used in petroleum engineering applications in order to model the static and dynamic characteristics of hydrocarbon reservoirs. However, the fundamental concepts used in estimators and simulators do vary from each other leading to the necessity of choosing the optimal approach with an extensive care. Geostatistics is perhaps the most widely used technique in simulation which is popularly used in different engineering applications and specifically in reservoir simulation. In this paper, three shortcomings of geostatistics in estimation and simulation are highlighted and alternative methods are proposed. Firstly, Kriging estimator, as is used in geostatistics, guarantees minimum estimation variance if the variogram model is the optimum fit and stationary conditions are met. However, in real situation, these conditions are not always satisfied. Geostatistics is prone to number of deficiencies some of which are discussed in this paper in the context of oil and gas applications and alternative solutions are presented. As such, the incapability of variogram, as being the fundamental tool in geostatistical analysis, in capturing the periodic structure of reservoir formation is shown. Then, it is discussed why the use of signal decomposition tools such as Fourier, fast Fourier and wavelet transform is more advantageous than variogram in this context. Secondly, to overcome the smoothing property associated with geostatistics fractal simulation is recommended as an alternative approach. Finally, it is discussed how intrinsic properties of reservoir can be included in multi-fractal or neural network to improve the estimation and simulation process. This appears to be difficult to apply if geostatistical approaches are used for estimation or simulation purposes.
Record Propped-Fracture Stimulation Performed from a Jackup Rig in the North Sea
Authors: Robertson Bruce , Ridley Elizabeth , Atchison Bryan 
Published: February 2010

Abstract
Proppant-based hydraulic-fracture stimulation in the southern North Sea is becoming increasingly popular and, in some marginal fields, can be considered crucial to maximize reservoir contact; thus, improving deliverability from tight-gas sandstone formations. Because of the low availability of purpose-built or temporary stimulation-class vessels in the North Sea, an alternative concept to place more than 250,000 lbm of proppant into well 49/17-14 from the Ensco-100 jackup rig was proposed, reviewed, and successfully executed.
This paper presents the prejob engineering process and executional summary of the North Sea’s largest rig-based proppant-fracture stimulation, where in excess of 250,000 lbm of resin-coated proppant was placed at fracturing rates of 35 bbl/min, with greater than 7,000 hydraulic horsepower available.
Discussed within this paper are prejob planning measures and the logistical challenges overcome during completion of the project. In addition, the paper introduces the first use of a microemulsion surfactant in the North Sea to help optimize cleanup time by reducing in-situ capillary pressure.
The overall success of this project proves there is a viable commercial and technical alternative to vessel-based fracture stimulation in the North-Sea market where suitably sized rigs are available.
Precise Method Using Resistivity Imaging Tool for Estimation of High Resolution Reservoir Parameters Calibrated to Reservoir Description Tool and Nuclear Magnetic Resonance Data for Better Reservoir Characterization
Authors: Reda Ahmed , Hakim Hashem Abdel 
Published: February 2010

Abstract
This paper explores a successful method for predicting high-resolution saturation, permeability, and porosity from resistivity imaging acquired with wireline logging. By integrating the best attributes of resistivity imaging and both wireline NMR and pressure testing information, this method is shown to produce better reservoir evaluation and production enhancement when applied to a homogenous sandstone reservoir that is relatively free from micro-bound porosity and layering.
Three available wireline formation evaluation technologies used in concert with conventional macro-wireline logs can substantially improve reservoir evaluation in terms of porosity, permeability and saturation. These technologies include the following: Nuclear magnetic resonance (NMR), includes tools such as the MRIL®-Prime tool, which provides accurate estimates of formation porosity, permeability, saturation, and hydrocarbon properties, albeit with relatively coarse vertical resolution compared to resistivity images, which can be enhanced by post-processing techniques.Resistivity imaging, such as the X-tended Range Micro Imager (XRMI™) tool with vertical resolution down to 0.10 in. These tools provide high-resolution porosity, permeability, and saturation prediction in clastic reservoirs based on estimates of micro-bound and producible porosity by means of integration with NMR and conventional logs.Pressure and sampling tools, such as the Reservoir Description Tool (RDT™) formation tester, which provides reservoir pressure, anisotropy, lateral and vertical connectivity, producibility, and fluid mobility measurements, which can be converted to permeability using fluid viscosity from fluid sampling.
The new method uses a special post-processing technique for enhancing the vertical resolution of the NMR data. By providing reliable and accurate predictions of saturation, permeability, and permeability, the method integrates NMR-bounded porosity, conventional resistivity, and the NMR saturation resulting from the magnetic resonance imaging analysis (MRIAN™) post-processing model.
Waterflooding Performance in Inclined Communicating Stratified Reservoirs
Authors: El-Khatib Noaman A. 
Published: February 2010

Abstract
A mathematical model is developed for performance prediction of waterflooding performance in communicating stratified reservoirs with a dip angle from the horizontal. The effect of the gravitational force is reflected by a dimensionless gravity number in the fractional flow formula that accounts forthe dip angle and density difference between the displacing and displaced fluids. The developed modelis used to estimate the fractional oil recovery, the water cut, the dimensionless time and the injectivity ratio at times of water breakthrough in the successive layers. Eqations are also derived for the case of continuous log–normal permeability distributions characterized by the Dykstra–Parsons variation coefficient VDP or the standard deviation of thelog–normal distribution σk.
Solutions for inclined communicating stratifiedsystems with log normal permeability distribution were obtained and the performance was compared withthat of the horizontal systems. The effects of the gravity number, the mobility ratio and the Dykstra-Parsons permeability variation coefficient, VDP, on the performance are investigated and discussed.
The obtained results showed that the gravity effect of the dip angle enhances the performance in terms of delayed water breakthrough, higher fractional oil recovery and lower water cut. This improvedperformance is more significant in the case of unfavorable mobility ratio. Reservoir dipping does not affect the pseudo relative permeability functions but results in a decrease in the injectivity ratio
Optimization of Water Injection Facilities in Mature Field
Authors: AlKhalifa Mohammed H , AlKhalifa Hani H 
Published: February 2010

Abstract
This paper will discuss in details the balance between disposal system flexibility and system efficiency. Typically such systems are designed with some uncertainties from reservoir performance and production rates. This fact encourages designers and operators to oversize the system to be in the safe side. However, this approached comes on the expense of efficiency.
This paper describe an efficient approach to evaluate the existing water handling system within upstream facilities in terms of capacity and operation cost and to define the required upgrades and areas of optimization. This approach applies to upstream Gas Oil Separation Plants where produced water is gravity separated, treated and re-injected back into the producing formation. Water is therefore accounted for in the injection over all mass balance calculations.
The paper will show a new approach to effectively analyze produced water disposal systems and evaluate alternatives to significantly improve their efficiencies. This approach evaluates the whole system from the suction of the disposal pumps to the bottom of the disposal wells of multiple facilities simultaneously. Addressing the reservoir pressure, headers and laterals, pumps configuration and drive mechanism in details to be able to accurately balance required flexibility and improve efficiency. This approach addresses both short and long term optimization needs.
Prediction of Porosity and Permeability of Oil and Gas Reservoirs Using Hybrid Computational Intelligence Models
Authors: Anifowose Fatai , Abdulraheem Abdulazeez 
Published: February 2010

AbstractThis work utilizes the capabilities of Data Mining and Computational Intelligence in the prediction of two important petroleum reservoir characteristics, viz., porosity and permeability, based on the hybridization of three existing Artificial Intelligence techniques: Fuzzy Logic, Support Vector Machines, and Functional Networks, using several real-life well-log data.Two hybrid models have been built. In both, Functional Networks was used to select the best input variables for training directly from data using its functional approximation capability. In the first model, the selected input variables were passed to Type-2 Fuzzy Logic System to handle uncertainties, if any exists. These are then passed to Support Vector Machines for training and making final predictions using the test data. In the second model, the input variables selected by Functional Networks were passed to Support Vector Machines to transform them to a higher dimension, called a feature space, and then to Type-2 Fuzzy Logic to handle uncertainties, if any exists, extract inference rules and make final predictions using the test data. The results showed that the hybrid models perform better with higher correlation coefficients than the individual techniques when used alone for the same sets of data. This is a further confirmation of the theory that hybrids perform better than their individual components and possess the best qualities of each of the components. In terms of execution time, the hybrid models took less time for both training and testing than the Type-2 Fuzzy Logic, but more time than Functional Networks and Support Vector Machines. This could be the price for having a better and more robust model.The process of combining multiple computational intelligence techniques to build a single hybrid model has become increasingly popular. As reported in the literature, the performance indices of these hybrid models have proved to be better than their individual components when used alone.Hybrid models are extremely useful in the field of reservoir characterization in petroleum engineering which requires a high quality information and accurate prediction for efficient exploration and management of oil and gas resources.
Natural Gas Economic Challenges in North African Countries
Authors: Ellafi J. S 
Published: February 2010

Abstract
The strategic location of North African natural gas producers play an important role in attracting natural gas investors which the industry is very much in need of; to accelerate the development and procurement of gas projects both in the upstream and down stream sector.
North African countries need to tackle many challenges in order to make use of both local and foreign private investors that are anxious to participate in development of natural gas projects especially after recent increase in natural gas demand which concedes with energy price improvements, recent economic growth of many countries in the region played a major part in attracting local and foreign private fund to develop natural gas resources, risk management procedures to tackle these challenges are necessary for economic success of gas projects in the region. This paper outlines the difficulties and challenges that retard the development of natural gas industry in the North African region.
Enhanced Field Surveillance through Real-Time Data Visualization in Dubai Offshore Fields
Authors: Shnaib Fathi , Nadar Manickam S. , Chacon-Fonseca Joel 
Published: February 2010

Abstract
Dubai Petroleum (DP) currently has offline production optimization processes in place for optimizing Dubai’s offshore gas lifted assets, both at the well and system levels. In order to achieve real-time well surveillance and optimization capability for the whole asset, DP has deployed a field-wide real-time well performance monitoring system for all the producers and injectors in the entire asset. This paper describes the various phases of the real-time well performance monitoring project; justification, pilot test, full field implementation and current applications of this tool. The technical and economic benefits of such systems and the lessons learned from this implementation will also be discussed.
The "Data to Desktop" well performance monitoring system aids the engineers to review well performance related trends in a continuous manner. The system has helped identify well performance-related issues in a very short period of time and aided in solving these problems with less production downtime than before. The tool has helped reduce the time spent by engineers for data gathering and issue identification. As the system is web-enabled and deployed through the company’s Intranet, it is possible to monitor the live well performance from any location.
The Real-time "Data to Desktop" system will allow DP to progress to the next step of real-time production optimization. The raw well data will be "cleansed" from spikes, noise and bad-data periods and utilized for calibration of the well models. The output of the models when compared with the field data can be used to automatically highlight the wells that are sub-optimal in their performance.
Faced with ever growing pressure to produce maturing fields optimally, asset operators are turning to digital technologies to help maximize the time spent by engineers in greater value-adding activities, leaving data gathering, "cleansing", processing and visualization to systems such as the well performance monitoring system that was implemented.