bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluation of the Pressure Drop due to Multi Phase Flow in Horizontal Pipes Using Fuzzy Logic and Neural Networks
Authors: Attia M. , Mahmoud M. A. , Abdulraheem A. , Al-Neaim S. A. 
Published: December 2013

Abstract
One of the most important parameters affecting flow rate in oil producing wells is the pressure drop across the surface flow-lines. The pressure drop calculation in multiphase flow is very complicated due to the empirical nature of the correlations used and the high variation in gas and liquid hold up especially in hilly terrain and rough environment that will complicate the flow regime and make negative impact on well productivity. Scientists came up with two main approaches: empirical/experimental flow correlations and mechanistic models to overcome this difficulty. These two approaches are applicable within certain conditions where their accuracy in pressure drop prediction degrades outside their design boundary ranges.
The raising popularity of Artificial Intelligence (AI) techniques during the past two decades proved that AI can be an alternative solution to many of the problems where physics and classic statistics fail to provide satisfactory solutions. This paper describes the utilization of Fuzzy Logic and Neural Networks, which is one of the industry AI techniques in predicting the multiphase flow pressure drop in surface pipeline for oil fields using real testing data collected from oil fields. More than 240 published real well testing data were used in constructing the model.
After filtering the data and building the model, the newly developed AI model was the best method to predict the multiphase flow pressure drop. Prosper software was used to confirm the validity of the AI methods over the other existing correlations. The final results confirmed that Adaptive Neuro-Fuzzy Inference System (ANFIS) is more accurate than all the used correlations and Neural Networks. The ANFIS model resulted in .4% absolute average error compared to a range of 17.5% – 64.57 % for the compared correlations.
Sampling While Drilling Goes Where Wireline Can’t: Case Studies Illustrating Wireline Quality Measurements in Challenging Borehole Environments
Authors: Sanchez Francisco Galvan 
Published: December 2013

Abstract
In the early 2000s, formation pressure while-drilling tools were introduced that can obtain formation pressure data, even in highly deviated wells and extended-reach drilling. In the past two years, this LWD technology has evolved with the addition of downhole fluid sampling and fluid analysis. LWD sampling and testing is now performed in challenging environments that cannot be performed with wireline tools such as horizontal or highly deviated wells. The limitations of wireline deployment in these wells are because of the cumulative frictional resistance of the wireline, the toolstring components and the borehole where it is run. Although several technologies exist to mitigate the risks, such as fly wheels, wireline tractors or pipe-conveyed options, operators prefer to eliminate the risks and costs associated with them by utilizing LWD technology.
The first part of this paper describes the new sampling and testing service that was designed for the LWD environment. The service has several closed-loop control systems for pressure testing, mobility determination and pumping during sampling and cleanup operations. In-situ fluid analysis is achieved with sensors that measure optical refractive index, sound speed, density and viscosity. Downhole fluid samples are retrieved with single-phase tank technology.
The second part of this paper details case studies of field tests that were performed for a major operator in Trinidad and an IOC in the Netherlands. In Trinidad, the service successfully performed pressure testing, real-time fluid analysis and recovered three single-phase samples while drilling a 300ft section at a 70° deviation. On a dedicated logging run in the Netherlands, the service first accurately took 25 formation pressure points and clearly identified three distinct gradients. The customer targeted four zones of interest and acquired 11 samples: six single-phase samples in the oil zone, three single- phase samples in the water zone and three single-phase samples in the gas zone. The pressure testing and sampling was executed in a 1,307 m tangent section at a 73° inclination. The service was utilized to determine the presence of moveable fluids in the reservoir of a horizontal development well for a customer in Norway. The tool was positioned at a sampling station with a mobility of 1.8 mD/cP; after nearly five hours of pumpout at that station, it successfully acquired the first sample, and after another four hours at the same station, the tool acquired the second sample.
In both cases, the LWD sampling and testing service was chosen over wireline to mitigate the risks of sticking during the sampling and pressure testing operation. These field tests demonstrated that the LWD service is capable of taking wireline-quality measurements in extremely challenging borehole environments.
Advanced Workflow for 3-D Geological Modeling of a Complex Giant Field, Greater Burgan, Kuwait
Authors: Filak Jean-Michel , Van Lint Julien , Ali Farida , Ma Eddie , Al-Houti Reham 
Published: December 2013

Abstract
The Burgan-Wara formations from Southeast Kuwait (Greater Burgan field) constitute the largest known siliciclastic oil reservoir on earth. A specific workflow combining geological, geophysical and reservoir engineering techniques was developed to build a fully integrated and representative geomodel of the field.
The sedimentology and stratigraphy were here reviewed in terms of depositional environment and lateral stratigraphic correlation. The variability inherent to the depositional style leads to a complex reservoir scheme. Lower Burgan is dominated by stacked braided channels representing homogeneous, high quality reservoirs. Higher in the stratigraphy, lateral facies variability and heterogeneities are observed in tidal dominated units. Mud dominated units occur within the Upper Burgan and Lower Wara formations and provide good sealing capacities. Small, laterally strongly variable and heterogeneous fluvio-tidal dominated units are representative of the Upper Wara Formation.
A 3D geological model of more than 900 million cells was built, based on the new structural and stratigraphic framework interpretations to capture the complexity of the Burgan Field reservoirs. Rock-types were defined, based on more than 900 well logs and core petrophysical properties measurements. The seismic reservoir characterization, focused on inversion techniques and calibrated with the newly defined rock-types provided crucial information on sandstone proportions distribution, especially in areas with lower well control.
The first attempt to simulate, at high resolution, the largest siliciclastic oil field in the world provides a comprehensive way to understand the field heterogeneities and behavior. The updated geological model, based on new interpretations allowed characterizing the major reservoir heterogeneities and has significant impact on the reservoir management of this giant field.
Application of the Gas Handlers in KOC
Authors: Rahime Farouk , Sakr Karim , Areekat Moossa , Suryadi Richard 
Published: December 2013

Abstract
This paper presents the experiences of using multi-vane gas handling pump stage (MVP) at the RQ/AD field in electric submersible pump (ESP) completed wells that have gas production. KOC repeatedly experienced short run times due to the gas issue including after the switching off or tripping the ESP. Upon restart, the gas damaged the ESP, causing premature failure.
The MVP pump is an industry first to overcome this issue that has plagued ESP users for years. The new technology tool is designed to enhance the run time of ESPs in gassy wells.
The MVP features a unique, patented impeller design that enables the pump to continually operate while producing substantial lift in fluid conditions up to 70% free gas, subject to the constraints of the Turpin Correlation. The MVP pump technology was extensively tested in high pressure gas test loop; this unique, highly instrumented state-of-the-art testing facility is the only one of its kind in the industry and is used to aid the design development and evaluation of gas handling technology. MVP can be used alone or employed as a charge pump in a standard ESP system. MVP can be combined with the BH GM Series gas separator for applications with greater than 90% free gas.
The BH MVP was used in KOC specifically (RQ/AD) field in Kuwait; this paper outlines the improvements seen as a result of utilizing the MVP technology.
Coiled Tubing As A Sucker Rod As Well As Production String In Dual Zone Completion
Authors: Parekh-Pandit Rathin P. , Desai-Pandit Krupesh 
Published: December 2013

Abstract
Technological advances in coiled tubing, Coiled Tubing handling equipment, and application techniques have provided new opportunities for the effective, economic use of Coiled Tubing in various fields of petroleum industry. The technology is still in the process of testing its boundaries and limitations. However, this is a necessary phase in the learning curve. Probably the most logical approach is to consider the market or application niches best suited to coiled tubing drilling technology.
Evolution of the coiled tubing Production process is one of the most exciting and fastest growing sections of the coiled tubing industry. In Dual zone completion, production is conventionally carried out using parallel tubing string completion or tubing annulus completion. In this case implementation of artificial lifts is difficult. This difficulty could be overcome by the use of coiled tubing, sliding sleeve and an anchor.
This paper presents a review of the CT capabilities that can be used in dual hole completions. This paper intends to discusses the guidelines of applicability of Coiled Tubing and design considerations for using Coiled Tubing as a sucker rod and also as production string in dual zone along with the pros and cons of coiled tubing. We have concluded our paper with some relevant recommendation on some operational and design strategies as well as future direction for integration of additional variable
New Technique to Identify Multiple Contaminated Primaries in Full-Stack Seismic Data and Possible Mitigation Measures: Gotnia Basin (Northwest Kuwait)
Authors: Heyam Ammar , Banik Nikhil , Adwani Talal Fahad , Ahmed Manowar , Srigiriraju Ramachandra 
Published: December 2013

Abstract
We present a case study with regard to multiple contamination of seismic data in post-stack 3D seismic data in the North Kuwait Gotnia subbasin, which holds very good hydrocarbon potential within Pre-Cretaceous reservoirs but faces considerable challenge in reservoir characterization because of its multiple contamination. This study attempted to focus mainly on the Pre-Cretaceous carbonate reservoir around the KM structure.
The main challenge is to deal with interference of 5th or 6th order peg-leg multiples with primary signals at the reservoir level. Peg-leg multiples are instances of short-path, multiple reflected seismic energy that can directly impact the seismic inversion results, facies mapping, structural interpretation, and hence depth prediction.
The improved approach to multiple attenuation could be demonstrated by a pilot processing using the following techniques on select locations. The new technique delineates a spatial an area which may be contaminated with multiples in post-stack 3D seismic data. First step tool for interpreter.Key elements gained from this method to implement multiple mitigation measures, which can reduce the multiple-contamination effect in post-stack data are: ∘Identifying spatial area of contamination by observation by horizon flattening.∘Nature of amplitude contamination over structurally favourable locations.The interference may indicate the nature of multiple contamination. This method is subject to testing.
A new approach to identifying and interpreting multiple contaminated primaries in full-stack seismic data provided a better interpretation of data for the North Kuwait Gotnia sub-basin. It revealed need for more multiple modeling and vertical seismic profiling (VSP) in all wells. However, it also provides a methodology for reprocessing for all available 3D seismic data through multiple mitigation that can improve seismic inversion, reinterpretation, geomodeling on newly processed 3D seismic data
Enhanced Oil Recovery by Nanoparticles Injection: Modeling and Simulation
Authors: El-Amin Mohamed F. , Sun Shuyu , Salama Amgad 
Published: December 2013

Abstract
In the present paper, a mathematical model and numerical simulation to describe the nanoparticles-water suspension imbibes into a water-oil two-phase flow in a porous medium is introduced. We extend the model to include the negative capillary pressure and mixed relative permeabilities correlations to fit with the mixed-wet system. Also, buoyancy and capillary forces as well as Brownian diffusion are considered. Throughout this investigation, we monitor the changing of the fluids and solid properties due to addition of the nanoparticles and check for possible enhancement of the oil recovery process using numerical experiments.
Marcellus Shale Gas Asset Optimization Driven by Technology Integration
Authors: Kaufman Peter , Atwood Keith , Forrest Gary , Walker Kirby , Wutherich Kevin , Delozier Denise , Perakis Alex , Borchardt Shannon , Hauser Ken 
Published: December 2013

Abstract
Integrating logging-while-drilling (LWD) measurements with pilot well log data and 3D seismic data provides a more accurate predictive mapping of unconventional reservoir properties than evaluations from the individual measurements alone. In this project, the final probability of drilling in a zone of good reservoir quality, as defined by the seismic attributes, had the highest correlation with production of any spatially mappable variable and provided the operator with a ranking of potential drilling locations. This link between production drivers and causal mechanisms allows optimal decision making, partly by distinguishing reservoir quality variation, which cannot be controlled, from operational behavior, which can be modified; untangling these two can mean optimal use of capital resources to exploit these challenging reservoirs.
Understanding Reservoir Properties Through High-Definition Microresistivity Images in Horizontal Shale Oil Wells Drilled with OBM in China
Authors: Yun Xie , Huijun Hou , Hui Guan , Laronga Robert J. , Zhongbin Xin 
Published: December 2013

Abstract
Oil-base mud (OBM) is an increasingly popular drilling fluid used to protect the wellbore stability in horizontal wells drilled in China targeting shale gas or oil. In these reservoirs, an in-depth understanding of fracture attributes is critical for stimulation design and well placement optimization, but the resolution and coverage of traditional imaging technology for OBM limits the extent to which this objective may be achieved. A microresistivity imager achieving resolution and coverage similar to established technology for conductive water-base mud (WBM), fully capable to distinguish fractures and formation structural features in OBM, has been a much needed technology development to provide critical insight required for shale oil exploration.
The paper presents a case study from the Bohai Bay basin in Eastern China, where oil shale formed in the faulted depression lacustrine sub-basins of the Lower Oligocene. One horizontal exploration shale oil well was drilled with OBM for reservoir evaluation. Only a gamma ray log and new, high-definition microresistivity image logs were acquired due to difficult operating conditions, which made it a great challenge to interpret reservoir properties and optimize stimulation design. Fortunately, two nearby vertical wells were drilled and evaluated in detail prior to design of the horizontal well, making use of geochemical, advanced acoustic, and microresistivity image logs to optimize placement of the lateral, thus providing a reference for estimation of the reservoir properties.
The results showed that the new, high-definition resistivity imaging tool gives detailed images suitable for full fracture and structure characterization, and that such high-quality images are feasible even in wells drilled with OBM. Interpretation of high-definition microresistivity images to build a near-well structural model provided a framework for correlation of fracture, reservoir, and mechanical properties from the vertical wells to the horizontal well. This provided a clear picture as to how the lateral well trajectory progressed stratigraphically within the shale section, as well as the distribution of the fractures, reservoir and non-reservoir rocks, total organic carbon (TOC) and minimum geo-stress along the well trajectory. Subsequently, this rich model provided the needed critical inputs to decide how and where to complete the well with an optimized stimulation design.
Innovative Methodology to Riglessly Restore the Functionality of the Sub-Surface safety valves Sc-SSSV with Damaged Control Line
Authors: Fahim Mohamed , Elnaggar Hossam , ElBarbary Abd Allah , Arab Mohammed Abu , Keshka Ashraf , Daghmouni Hamdi Bouali , Al Karra Mohamed , Soufan Ammar , Joseph O’Connor , Elasmar Magdi 
Published: December 2013

Abstract
The company introduced a new era of Well Integrity Management system as a continuous assessment and verification process to ensure the integrity of the wells is designed, monitored and maintained throughout the well life cycle.
Failure of any well barriers is not allowed. If a barrier fail, an immediate action should be taken to restore the well integrity, which is one of the important business elements in oil and gas fields; and hence according to well integrity standards utilizing well control devices are mandatory to protect human life, and reduce the potential for environmental pollution in addition to minimize the loss of production.
The surface control subsurface safety valve (SC-SSSV) is an integral part of the overall safety system of any well and it is the only method that provides sub-surface isolation in case of emergency due to uncontrolled surface or sub-surface event. Therefore it is mandatory to have functional SC-SSSV installed in the production tubing in all gas and oil wells, irrespective of their location, to stop the flow in case of a catastrophic failure.
The SC-SSSV is adjusted to be held in the open position by hydraulic positive pressure from surface. This pressure is applied through a control line in the tubing-casing annulus running from the valve to the surface. In case of an emergency shutdown the hydraulic pressure will be released forcing the safety valve to close. However the control lines could leak, plug or break leading to losing the functionality of the safety valves. The only way to rectify SC-SSSV C/L problems is by a rig work-over to replace with new C/L.
This paper describes the innovative methodology, which is the first application in the UAE & Middle East, to install Baker Hughes system "Inject-safe" controlled sub-surface safety valve which has a similar operating philosophy to the conventional SC-SSSV. The "Inject-safe" C/L deployment is on the inside of the tubing which drastically reduces the cost. This unique approach has been successfully executed in one of the super giant onshore fields in Abu Dhabi through an extensive techno-economical study.
The paper goes through the methodology of candidates’ selection, the system requirements and modification in wellhead and the trial results through specific testing criteria in one of the wells as part of a field pilot. The risk assessment is also discussed along with the execution process.
The cost impact of installing the new system as proved in the pilot through a techno-economical evaluation well will be highlighted, in addition to well performance pre/post installation combined with the project conclusion and recommendation for future implementation.
A New Artificial Lifting of High Productivity Wells: A Production Optimization Scheme
Authors: Qahtani Abdullah Al 
Published: December 2013

Abstract
The need for oilfield operators to verify that wells are being produced at their optimum capacity and in a cost effective manner is always a priority. The need for total well management to reduce operating costs, increase oil production and increase net income from wells requires an integrated analysis of the pumping system including the performance and interaction of all the elements: the reservoir, wellbore completion, and the downhole pump. Well Completion is typically designed to assure certain oil flow rate whilst producing manageable volume of water to ensure good reservoir sweep efficiency and management. Completion design is always based on collected production data of forecasted reservoir performance of changing pressure and water cuts.
As oil fields mature with subsequent increase of water cut and decrease in pressure, artificial lifting is becoming a vital mechanism for maintaining the production plateau of the field. With the emergence of the inflow control devices (both passive and active), the thrust for artificial lifting is delayed due to the delay of onset of water production or reduction of water volume produced. Very recently, the industry has looked into combining artificial lifting with controllable inflow devices.
This paper addresses the different optimization scenarios of well completion in high productivity wells considering the life cycle of artificial lift systems (mainly ESP’s) and different flow control mechanism. The paper highlights cases of applications extreme values of water gravities. In addition, underlines the economic viability of artificial lifting due to maintaining production and reducing cost in some applications.
Multi-attribute Seismic Analysis using Fractal Dimension and 2D & 3D Continuous Wavelet Transform
Authors: Saraswat Puneet , Raj Vijay , Sen Mrinal K. , Narayanan Arun 
Published: December 2013

Abstract
3D post-stack seismic attributes provide an intuitive and effective way of utilizing seismic volumes for reservoir characterization and development, and further identification of exploration targets. Some of the seismic attributes can aid in precise prediction of geometry and heterogeneity of subsurface geological settings. These can also provide useful information on petro-physical and lithological properties when combined with well-log information. There exist numerous seismic attributes providing unique interpretation on some aspects of subsurface geology. Of these, proper demarcation of structural features, such as location and edges of faults, salt domes, their throw and extent, has always been of primary concern. In this paper we propose new multi-attribute seismic algorithms using fractal dimension and 2D/3D continuous wavelet transform (CWT). The use of higher dimensional wavelets incorporates information from ensemble of traces and can correlate information between neighboring traces in seismic data. The spectral decomposition based on CWT aids in resolving various features of geological interest at a particular scale or frequency, which when rendered with fractal attribute demarcates the boundaries between those. We apply these two algorithms separately to a seismic amplitude volume and co-render output volumes together with some weights to yield a final attribute volume incorporating information from above mentioned algorithms. We demonstrate the efficacy of these two algorithms in terms of resolution and proper demarcation of various geological structures on a real seismic data. Results illustrate better illumination and proper demarcation of various geological features such as salt domes, channels, faults etc. at a desired frequency and how simple mathematics can provide tools to extract most of the information from seismic data.