bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pinpointing Irregularities in a Well's Integrity: Case Study
Authors: Al-Thwaiqib Ibrahim , Ghanmi Ahmed , Al-Mulhim Abdullah , Bawazir Mustafa 
Published: July 2016

Abstract
Although early corrosion detection may allow preventive maintenance to reduce the risk of environmental damage and surface incidents (explosion, fire, leakage, and related consequences), many of the wells producing today were completed decades ago, when corrosion control and monitoring were not a primary concern. Even with today's technological advances, corrosion cannot be completely prevented, but it can be controlled and minimized through proper planning, monitoring, and maintenance.
Middle Eastern operators have experienced varying degrees of casing completion failures in recent years due to common highly corrosive, water-bearing zones across shallow depths. The electromagnetic (EM) pipe inspection tool provides critical monitoring for evaluating casing integrity by locating, identifying, and quantifying damage and corrosion. Failure to address potential corrosion attack can impact well profitability as operators must respond by implementing extensive and potentially expensive restoration methods. Not only does mitigation increase operating expenses, it may force operators to shut-in well production for unplanned periods of time.
The immediate aim of the examples presented in this paper is to understand the levels of corrosive damage that are present in the wells; that have serious repercussions on the flow efficiency of completions. This assessment of well integrity investigations is used to identify any extensive corrosion in the outer casing before it penetrates through the inner casings. The provided field examples were logged rigless to establish the condition of multiple pipes. Corrosion intervals were suspected of being responsible for reducing well performance and killing the wells. Casing metal loss (ML) evaluations assisted in identifying which wells need workover attention to avoid excessive loss in production, environmental pollution, repair costs, or accidents.
New Data-Driven Method for Predicting Formation Permeability Using Conventional Well Logs and Limited Core Data
Authors: Shabab Mohamad , Jin Guodong , Negara Ardiansyah , Agrawal Gaurav 
Published: July 2016

Abstract
The need for improved data accuracy, cost effectiveness and delivery time to assist in decision making has gained importance in reservoir characterization and evaluation. This paper presents a robust and inexpensive data-driven method for predicting the formation permeability profile from conventional well logs (CWLs) using the support vector regression (SVR) technique with limited core measurements. The method's feasibility and applicability are demonstrated on one field data set from a North Sea well contained a complete suite of logs and extensive core measurements.
The relationship between formation permeability and well logs is often overwhelming complex and nonlinear. We use the SVR method to establish the correlation between CWLs and limited core permeability, thereafter building a permeability-prediction model as a function of selected well logs. The basic logging data used here include density, neutron, deep resistivity, compressional and Stoneley wave slowness. The permeability derived from these well logs generally compares well with the measured core permeability. Additional logging data including the clay weight fraction, thorium/potassium content, or nuclear-magnetic-resonance (NMR) bulk volume movable and irreducible are also separately integrated into those basic logs to determine if the prediction accuracy can be improved. There is no obvious difference among the predicted permeability profiles even these additional well logs are added, which could imply that the basic logs are sufficient to generate the permeability with good accuracy.
SVR method could be used to improve the log interpretation accuracy as shown in this study. It can be easily adapted to predict other rock electrical, mechanical and petrophysical properties when only conventional logs and few core measurements are available. It is especially useful for unconventional reservoirs where traditional models may not be applicable and new methods are still evolving. Such new data analysis technologies could optimize our logging service and core analysis planning.
Assessment of Capillary Pressure Heterogeneity to Optimize Oil Recovery & Development Cost of Carbon Dioxide Floods
Authors: Al Sulaiman Ahmed A. , Krinis Dimitrios , Hossain M. Enamul 
Published: July 2016

Abstract
Carbon dioxide injection has been widely used as an EOR process, even in carbonate reservoirs with complex rock system. In order to enhance the post water flooding recovery, CO2 exposure with the remaining oil in lower zones should be maximized. This is a great challenge, as CO2 is considerably lighter than oil making gravity the dominant force. However, reservoir complexity can influence CO2 penetrating distance before a complete gravity segregation occurs. Therefore, understanding the reservoir heterogeneity and corresponding impact on oil displacement is a key to successful CO2 flooding projects. Particular focus was placed on vertical variation of oil-water capillary pressure and relative permeability curves.
This paper provides a detailed assessment of heterogeneity based oil-water capillary and relative permeability curves on ultimate oil recovery by CO2 floods. In addition, it studies the effect of CO2 vertical placement, well type, CO2 injection rate, and simultaneous CO2 and water injection on recovery. This was achieved with a numerical simulation approach using a commercial simulator, ECLIPSE. Numerous sensitivities were carried out with a conceptual 3D model undergoing water and CO2 flooding to optimize ultimate recovery at minimum cost. The investigation is based on two scenarios in which the complexity of the vertical capillary and relative permeability curves was varied.
The results from both scenarios showed consistent trend indicating that the variation in oil-water capillary and relative permeability curves can influence the oil- CO2 exposure thereby affecting the ultimate recovery. Among the considered factors, CO2 injection rate has the greatest influence on the ultimate recovery. The heterogeneity in capillary pressure and relative permeability causes CO2 to penetrate longer distance before a complete tonguing occurs. The maximum oil- CO2 exposure was achieved in the case where the highest contrast in such transport properties exists between the top zones. At higher CO2 injection rates, additional recovery gains were achieved as CO2 penetration was enhanced further by viscous force. The recovery gain increases even more with simultaneous CO2 and water injection. Moreover, results obtained from shallower water and deeper CO2 injections were encouraging. The effect of CO2 placement was found of a concern only in cases where the highest capillary pressures exist in the top zones. Limited effect was observed by the well type, thus injection of CO2 in shallower layers in vertical wells could be a cost effective option. The ultimate oil recovery for both scenarios post-optimization has increased remarkably compared to water flooding and CO2 pre-optimization cases.
Collosion Avoidance Awareness and Mitigation Measures
Authors: Dabyah Ali Al , Sananiry Abdel Rahman , Al-Shehri Fayez 
Published: July 2016

Abstract
Collision avoidance, one of the hottest subjects in the oil and gas industry, must be treated as high priority before executing any drilling programs. Wellbore collision avoidance procedures have a huge impact on the wellbore placement for targetson many desired reservoirs. A well planner/ drilling engineer must perform these procedures at the very beginning of the well planning stage, especially if the drilling involves platforms. Having a trusted historical database of the field is crucial, and this is where the integrity of the survey database and the survey programs provided by client must be reviewed very carefully. Any human error, software malfunction, or incorrect surveys can lead to major accidents at the rigsite, death of, worker injuries, environment pollution and financial losses.
This paper discuss the basic clearance calculations that indicate how far away one wellbore is from another and the mitigation measures that should be followed to have a valid collision avoidance procedures.
A Numerical Investigation on the Performance of Alkaline-Surfactant-Polymer Flooding in Naturally Fractured Carbonate Reservoirs
Authors: Mohammed Marwan N. , Hossain M. Enamul 
Published: July 2016

Abstract
Naturally Fractured Reservoirs are important contributors to the world's oil and gas reserves representing around one-fifth of the world's reservoirs. They usually are of lower recovery and higher residual hydrocarbon saturation than the rest of reservoirs due to its mixed wettability, low matrix permeability, low fracture porosity, and the complicated fracture network. When alkaline-surfactant-polymer flooding is conducted, it enhances the recovery by altering the wettability, lowering the interfacial tension of the rock, reducing the mobility ratio, and forming a secondary in-situ surfactant, consequently reducing the residual hydrocarbon saturation. However, majority of ASP operations usually underestimate the complicated structure and description of reservoirs. As a result, this lacking causes a serious flood modeling issue on NFRs since they rely on the matrix system mainly being the storage of hydrocarbon, and the fracture system carrying out the production.
This paper presents a comprehensive study on modeling ASP flooding on NFRs. It mainly addresses the effects of wettability, IFT, capillary forces, fracture parameters along with fracture and matrix permeabilities on ASP using a dual porosity and dual permeability model. It also addresses the performance, recovery factor and the optimum slug size for an optimum EOR operation, as well as to give guidelines and theoretical justification for better flooding practices based on a modeling approach only.
Sensitivity analyses on the constructed model of slug size, initiation time, sequence of injection, and concentration are done. Results show the optimized slug sizes of the injectants (i.e. 200 stb/day: 1 year of pre-injected water, 2 years of AS slug and 2 years of ASP slug), optimum initiation time and sequence of injection (1 year of water pre-injection followed by the ASP slug then followed by water flooding), in addition to the optimum concentrations of chemical injectants (alkaline and polymer concentrations of 50 lb/stb each, and surfactant concentration of 30 lb/stb). Also sensitivity analyses on the mentioned parameters are conducted and the results show how they affect NFRs. The study introduces a non-conventional injection method named Cyclic Alkaline-Surfactant-Polymer flooding. The performance and effectiveness of C-ASP are presented in addition to a comparison between C-ASP and conventionally used methods.
Simulation of Ionic Liquid Flooding for Chemical Enhance Oil Recovery Using CMG STARS Software
Authors: Dahbag Mabkhot S. , Hossain M. Enamul 
Published: July 2016

Abstract
A significant portion of crude oil remains in the reservoir after the application of conventional recovery. To meet the growing demand for energy, enhanced oil recovery (EOR) methods should be used efficiently to recover the extra amount of trapped crude oil after water flooding. Surfactant flooding is one of chemical EOR methods that can be implemented to recover oil from the remaining oil-in-place. Ionic liquids (ILs) which are salts having a melting point below 100 °C, can be considered as a prospective alternative to surfactant because of their superiority on surfactant in different points. Ionic liquids have unique advantages such as low cost, low toxicity, recyclable and high ability to work in harsh environments. In this work, three simulation runs were conducted to simulate core flooding experiments with an ionic liquid solution at different scenarios. Surfactant flood model (SFM) which is available in CMG STARS software was used to match the simulation results of oil recovery, well bottom-hole pressure, and imbibition relative permeability curves with flooding experimental results. The purpose of this paper is to prove the validity of core flooding experiments with ionic solutions to be simulated with SFM model. In addition, transfer the experimental work to simulation in order to facilitate the performance of other scenarios and to predict the future results through flooding with an ionic liquid solution. All three scenarios have given a good matching between simulation and real data of oil recovery, well bottom-hole pressure and imbibition relative permeability curves. Both simulation and experimental results indicated that secondary continuous flooding with IL solution gives oil recovery (71% original oil in place, OOIP) greater than secondary slug size flooding (64% OOIP); whereas tertiary flooding with IL solution was the lowest one with 48% OOIP.
Challenges for Extending the Application of Nanoparticles in High Salinity Reservoirs
Authors: Al Hamad Mohammed , Sultan Abdullah , Khan Safyan , Abdallah Wael 
Published: July 2016

Abstract
Nanoparticles, through many researches, has proven its capability to be an enhance oil recovery agent. In this study, we aim to investigate the performance of natural Zeolite in nanoscale on the recovery of crude oil compared to the normal water flooding method. The natural Zeolite nanoparticles are dispersed in seawater, however nanoparticles stability in saline water have been reported to be a challenge. Therefore and in order to investigate the performance of these natural Zeolite nanoparticles on oil recovery, we first stabilize them in seawater. Natural Zeolite nanoparticles of different concentrations (i.e. 0.02, 0.03, 0.05 wt%) were dispersed in seawater, where stability tests showed nanoparticles precipitations in less than an hour. This problem, of nanoparticles precipitation in seawater, was investigated by studying the performance of the Zeolite nanoparticles in each electrolyte that exits in seawater. The study results showed good stability of the Zeolite nanoparticles in NaCl solution that has a concentration of 0.14 wt%, however Zeolite nanoparticles will destabilize at higher concentrations of NaCl. Divalent salts that exist in seawater (i.e. MgCl2 and CaCl2) were also tested. The Zeolite nanoparticles were found to be destabilized even at very low concentrations of these salts.
In the current work, we added surfactants to seawater to help in stabilizing the Zeolite nanoparticles. After initial screening of several surfactants, Polyvinylpyrrolidone (PVP) showed to be the best candidate to stabilize Zeolite nanoparticles in seawater. Experiments were then carried out using Zeolite nanoparticles plus (PVP) all dispersed in seawater. The effect of this dispersant on interfacial tension (IFT) was investigated where results revealed decrease in IFT values. The dispersant was shown also to change the wettability to more water wet condition which was due to the Zeolite nanoparticles, as a dispersant of only seawater and (PVP) was tested and found to not alter the wettability.
Characteristics, Behavior and Performance of ARC Plug- A Date Seed-Based Sized Particulate LCM
Authors: Amanullah Md 
Published: July 2016

Abstract
Saudi Aramco has developed a novel sized particulate LCM using eco-friendly natural date seed as the raw material. As there is a sustainable and large source of yearly supply of date seeds in Saudi Arabia and in the Middle Eastern Region, it has a great potential to be a viable source of raw material for manufacturing sized particulate LCMs in the Kingdom to help combat moderate to severe loss circulation problems encountered while drilling and cementing. This paper describes the characteristic features, behavior in drilling mud systems and performance of the date seed-based sized LCM product "ARC Plug" when incorporated into various water-based mud systems.
The newly developed "ARC Plug" has been tested and evaluated by incorporating in 65 pcf Bentonite mud, 73 pcf KCl-Polymer mud, 80 pcf NaCl-Polymer mud and 90 pcf CaCl2-Polymer mud widely used in drilling operation. A commercial sized particulate LCM marketed by an international vendor was also evaluated. Tests were conducted at 250 °F temperature and 1500 psi pressure using a 2mm slotted disc and the widely used PPT apparatus. Two different concentrations such as 10 and 30 lbs/bbl were used in each barrel of mud to evaluate their sealing and blocking performance.
The results demonstrated effective sealing and plugging capacity of the Saudi Aramco developed date seed-based sized particulate LCMs "ARC Plug". Both concentrations showed effective sealing and plugging of the slots to prevent the loss of whole mud through the 2 mm slots of the slotted disc. The commercial sized particulate LCM also sealed the 2 mm slot when incorporated in 65 pcf bentonite, 73 pcf KCl-Polymer, 80 pcf NaCl-Polymer muds and 90 pcf CaCl2-Polymer muds. However, the ARC plug showed relatively better performance than the commercial particulate LCMs. This pioneering research indicate that the locally derived novel and ecofriendly date seed-based LCM product is a viable alternative to commercial sized particulate LCMs to help control loss of circulation while drilling and cementing a well.
An Approach for Determination of the Economically Optimal Production Controlling Parameters from Water Drive Oil Reservoirs
Authors: Gamal M. , Khairy M. , El-Banbi A. H. , Saad S. M. 
Published: July 2016

Abstract
Significant effort usually goes into deciding the optimum completion and generating production forecast of new wells. However, due to uncertainty of certain reservoir parameters, the completion decision may not be optimum and may result in non-economic well. We focus in this paper on answering the following questions:(1) what is/are the optimum perforated interval(s)?, and (2) what is the optimum economic production rate for vertical wells in water drive oil reservoirs?. Obtaining the right answer for these two questions will give us the opportunity to make the right completion decision.
Several models are available to predict the critical coning rate. In many cases, the calculated critical rates are too low, and for economic reasons, wells are frequently produced at higher rates. In this paper, we present a new approach for the determination of the economically optimal production controlling parameters from water drive oil reservoirs.
In this approach, static and dynamic models are constructed to model the well and the surrounding reservoir properties. Two experimental design techniques are used to test the uncertainties in reservoir parameters and identify the most important optimization parameters. The model is linked to an economical model to calculate certain economic indicators. Then an optimization process is applied to find the optimum production controlling parameters to achieve maximum economic oil recovery.
Many cases were tested with this approach. Then, the optimization results were compared with the critical rate correlations' results. It was found that the chosen drawdown and perforation interval(s) provided safe operation range for water cut, while allowing reasonable economic gain. Therefore, this new approach is recommended over the available critical rate coning models, to define the optimum production controlling parameters to achieve optimum economic recoverable oil volumes in water drive oil reservoirs.
Effect of Preparation Depth on the Marginal and Internal Adaptation of Computer-aided Design/Computer-assisted Manufacture Endocrowns
Authors: Gaintantzopoulou MD , El-Damanhoury HM 
Published: July 2016

SUMMARY
The aim of the study was to evaluate the effect of preparation depth and intraradicular extension on the marginal and internal adaptation of computer-aided design/computer-assisted manufacture (CAD/CAM) endocrown restorations. Standardized preparations were made in resin endodontic tooth models (Nissin Dental), with an intracoronal preparation depth of 2 mm (group H2), with extra 1- (group H3) or 2-mm (group H4) intraradicular extensions in the root canals (n=12). Vita Enamic polymer-infiltrated ceramic-network material endocrowns were fabricated using the CEREC AC CAD/CAM system and were seated on the prepared teeth. Specimens were evaluated by microtomography. Horizontal and vertical tomographic sections were recorded and reconstructed by using the CTSkan software (TView v1.1, Skyscan).The surface/void volume (S/V) in the region of interest was calculated. Marginal gap (MG), absolute marginal discrepancy (MD), and internal marginal gap were measured at various measuring locations and calculated in microscale (μm). Marginal and internal discrepancy data (μm) were analyzed with nonparametric Kruskal-Wallis analysis of variance by ranks with Dunn's post hoc, whereas S/V data were analyzed by one-way analysis of variance and Bonferroni multiple comparisons (α=0.05). Significant differences were found in MG, MD, and internal gap width values between the groups, with H2 showing the lowest values from all groups. S/V calculations presented significant differences between H2 and the other two groups (H3 and H4) tested, with H2 again showing the lowest values. Increasing the intraradicular extension of endocrown restorations increased the marginal and internal gap of endocrown restorations.
Effect of Storage Time on Bond Strength Performance of Multimode Adhesives to Indirect Resin Composite and Lithium Disilicate Glass Ceramic
Authors: Makishi P , André CB , Silva JP Lyra e , Bacelar-Sá R , Correr-Sobrinho L , Giannini M 
Published: July 2016

SUMMARYPurpose: To investigate the bond strength performance of multimode adhesives (MMAs) to indirect resin composite and lithium disilicate glass ceramic after 24 hours or one year of water storage.Methods and Materials: Thirty flat and polished plates of indirect resin composite (Epricord) and thirty lithium disilicate glass ceramic plates (IPS e.max Press) were prepared. Surfaces were pretreated using sandblasting (indirect resin composite) or hydrofluoric acid (glass-based ceramic). Specimens were bonded with one of two MMAs (Scotchbond Universal [SBU] or All-Bond Universal [ABU]) or ceramic primer and hydrophobic bonding (RelyX Ceramic Primer and Adper Scotchbond Multi-Purpose Bond) as a control (n=10). Resin cement cylinders (0.75 mm in diameter × 0.5 mm in height) were bonded to both substrate surfaces using the respective adhesives. After 24 hours or one year of water storage, bonding performance was measured by microshear bond strength (MSBS) testing. Results were analyzed using three-way ANOVA with Bonferroni post hoc tests (α=0.05).Results: For indirect resin composite, significantly higher MSBS values were found for ABU after 24 hours (ABU &gt; SBU = control); however, no significant difference among the adhesives was observed after one year (p&gt;0.05). For glass-based ceramic, significantly different bond strengths were observed among the adhesives after 24 hours (control = ABU &gt; SBU) and one year (control &gt; SBU = ABU; p&lt;0.05).Conclusions: Both MMAs tested can be considered effective alternatives for bonding to sandblasted indirect resin composite after aging, as they showed similar bond performance to that of the control group. However, separate bottles of silane bonding resin showed higher MSBS values and more durable bonding for etched glass–based ceramic.