bluuebunny/crossref_metadata_2025_split huggingface dataset:
CO2 Minimum Miscible Pressure MMP Estimation using Multiple Linear Regression MLR Technique
Authors: Alomair Osamah , Iqbal Maqsood 
Published: June 2014

Abstract
Miscible gas injection processes are among the effective methods for enhanced oil recovery (EOR). A key parameter in the design of gas injection project is the minimum miscibility pressure (MMP), whereas local displacement efficiency from gas injection is highly dependent on the MMP. Because experimental determination of MMP is very expensive and timeconsuming, searching for fast and robust mathematical determination of gas-oil MMP is usually wished. A new CO2 MMP correlation based on Multiple-Linear-Regression modeling (MLR) technique has been successfully developed to more accurately estimate the CO2 MMP for a wide range of live and heavy crude oils. The newly developed CO2 MMP correlation is originated from CO2 MMP experimental data in addition to database from the worldwide published literature that covers 103 pure CO2 MMP data for various live and dead oil samples. The proposed model is trained by exploiting 80% (82 data points) of the data bank. This correlation is expressed as a function of reservoir temperature, C7+ molecular weight, mole fractions of; non-hydrocarbon components (CO2, H2S and N2), direct correlating components (C1, C2 and C5) and indirect correlating components (C3, C4, C6 and C7). Further, to investigate the authenticity in depth, the proposed correlation is compared with five most commonly used pure CO2 MMP correlations from the literature. A statistical comparison is performed for both training data set (82 data points) as well as testing data set (21 data points). It is found that the proposed CO2 MMP correlation provides the best reproduction of MMP data with a percentage average absolute error of 6.083% and 6.328% for training and testing categories respectively. Finally, the proposed model shows great performance using new set of samples compared with other correlations.
Foamability and Foam Stability of Several Surfactants Solutions: The Role of Screening and Flooding
Authors: Belhaij Azmi , AlQuraishi Abdulrahman , Al-Mahdy Osama 
Published: June 2014

Abstract
Foamability and foam stability are of main concerns in foam displacement for enhanced oil recovery. This work presents the output of systematic laboratory screening of foamability and foam Stability of several surfactants. The surfactants examined were Brij 700, Triton X-100, Triton X-405, Zonyl FSO, Hitenol H-10, Hitenol H-20, Noigen N-10 and Noigen N-20. Foam was generated by sparging Carbon Dioxide gas at a fixed flow rate through surfactants solutions and R5 parameter as suggested by Lunkenheimera and Malysa (2003) were used for foam stability testing. The results indicate the foamability of all surfactants except for Triton X-405. Zonyl FSO and Hitenol H-10 were superior in term of foam stability with more stability as surfactants concentration increases. Equivalent optimum foam volumes were obtained for both surfactants but at higher concentrations of Hitenol H-10.
Foam stability and oil displacement efficiency were tested with different concentrations of Zonyl FSO and Hitenol H-10 solutions. The presence of oil at the volume fraction implemented, affect the stability of the foam columns. The effect depends on the surfactant-type and surfactants concentrations where stability decreases at low Zonyl FSO concentration range and at all concentrations range tested of Hitenol H-10. In case of Zonyl FSO observations indicate that oil stayed in the lamellas skeleton and plateau boarders with no drain out. To the contrary, Hitenol H-10 was able to lift good portion of the oil column but oil was drained out of the foam structure within a short period of time.
Flooding tests on Berea cores proved the ability of Zonyl FSO and Hitenol H-10 in controlling gas mobility and improving the displacement efficiency. Hitenol H-10 was more efficient as indicated by the incremental oil recovery obtained and the higher pressure drop encountered. Hitenol H-10 Foam injection on tertiary gas flooded reservoirs improves residual oil recovery indicating the potential of the process even at late stages of gas injection.
State-of-the-Art of In-Depth Fluid Diversion Technology: Enhancing Reservoir Oil Recovery by Gel Treatments
Authors: Han Ming , Alshehri Amar J. , Krinis Dimitrios , Lyngra Stig 
Published: June 2014

Abstract
In contrast to near-wellbore conformance control applications, polymer gels are applied in injector wells for reservoir scale applications for in-depth fluid diversion (IFD). Novel gel systems include weak gels, sequential injection for in-situ gels, colloidal dispersion gels, preformed gels, and microgels. The objective of an IFD process is to modify the prevailing reservoir inflow profile by gel treating the reservoir to significantly reduce effective permeability of high permeability zones that would otherwise dominate the water uptake. The weak gels or gel particles are treated as a flowing fluid and are custom-made for reservoirs with fractures or high permeability zones. The very weak gels form near the wellbore region, but continue to propagate into the reservoir. The gels eventually stop propagating deeper into reservoir due to the variation in pressure gradients and pore structures. The subsequent injection of fluids, water or chemical solutions, will redirect predominate flow paths to unswept reservoir zones, which improves oil sweep efficiency by waterflood (or chemical flood); thus, leading to enhanced oil recovery. The technology presents distinctive advantages to high-salinity and high-temperature reservoirs as compared to polymer flooding due to stability of cross-linked gel structures.
This paper presents a state-of-the-art review of IFD technologies including weak gels, sequential injection for in-situ gels, colloidal dispersion gels (CDG), microgels, and preformed particle gels (PPG). Moreover, a solution to the challenges of IFD applications in high-salinity and high-temperature reservoirs is presented.
FAWAG Using CO2 Philic Surfactants for CO2 Mobility Control for Enhanced Oil Recovery Applications
Authors: Sagir Muhammad , Tan Isa M , Mushtaq Muhammad , Talebian Seyedeh Hosna 
Published: June 2014

Abstract
The application of CO2 injection for mobilization of trapped oil in porous media is the most frequently applied method for EOR projects. Despite of the fact that the CO2 injection can effectively mobilize the trapped oil, many problems such as viscous fingering, gravity override, high ratio of CO2 to oil produced and early breakthrough are required to be resolved. In this context, the injection of surfactant solution for the reduction of CO2 mobility is a promising method. However, until now surfactants usage for mobility control is facing many challenges such as, adsorption of surfactants on rock, requirement of copious amounts of water, and loss in the thief zones of reservoir. These challenges can effectively be reduced by employing CO2 soluble surfactants, which have exhibited more practical advantages over conventional surfactants. A study has been conducted to evaluate new CO2 soluble surfactants for the CO2 mobility control for EOR applications. The IFT between CO2 and synthesized surfactants solution was studied for the initial screening process and is reported. The coreflood experiments were conducted by using Berea core sample in order to measure the mobility reduction factor (MRF). The MRF value of 3.1 was obtained by the incorporation of 0.5 % of novel CO2 philic foaming agent. Moreover, it was observed that the IFT between CO2 and brine appreciably decreased by using the surfactant in 0.5 % concentration. Coreflood results showed that, as compared to conventional surfactants, newly developed CO2 philic surfactants significantly reduced the mobility of the injected CO2.
Innovative Hot Oiling Operation in a Low BHP Well Minimizing Formation Damage: A Case Study
Authors: Haindade Zishaan M. , Mamen A. M. 
Published: June 2014

Abstract
The most common oil field wellbore problem encountered is paraffin deposition in the production tubing. The crude oil production is impeded by accumulation of such waxy residues that tend to clog the tubing, perforations and pores of the reservoir rock through which the oil flows.
Hot oiling with the help of coiled tubing is usually the method applied for removing paraffin deposits, however there is a high possibility of significant amount of the fluid injected into the well being lost to the formation, and hence the potential to damage the formation with low bottom-hole pressure is high. One such case was encountered in a well operated by Oil India Limited and this paper provides details of innovative technique applied for successful execution of hot oiling operation in the low BHP well minimizing formation damage.
As the well had very low BHP, there was a need to use circulating fluid with density lower than that of the source oil utilized for conventional hot oiling operation. Hence, it was decided to carry out the job by using a mixture of hot oil and nitrogen gas so as to reduce the density of the circulating fluid, thereby avoiding loss of injected fluid to the formation.
This paper provides the case study of the successful operation carried out in the well along with the detail calculations of pumping rates and pressure of both hot oil and nitrogen gas to obtain the desired density of the circulating fluid.
Field Deployment of a Novel Inlet Device for Multiphase Separators - Steps from R&D to Industrial Application
Authors: Jutaily Sulaiman A , Charry Prada Iran D. , Haider Syed Z. , Oshinowo Lanre , Vilagines Regis D. 
Published: June 2014

Abstract
A patented separator inlet device (SID) technology developed at Saudi Aramco's Research and Development Center (R&DC) is underway for a field trail in a gas-oil separation plant (GOSP) high-pressure production trap (HPPT) in 2014. The function of the SID is to enhance phase separation by promoting droplet coalescence and gas separation for mixed fluids flowing into a horizontal gravity separator vessel.
The paper describes the steps taken to bring the new technology to field stage after a successful R&D phase, detailing the challenges associated with scaling up and field installation of the prototype. Close collaboration between the R&D team, Engineering Services and plant owners, under the supervision of strongly supportive management, was essential for rapid field deployment of prototype technology with unconfirmed impact on the production rate.
The procedure for selecting a candidate separator vessel for the field trial and process integration study will be discussed. The SID installation in the candidate HPPT required modification to the existing operating liquid levels, which triggered a process evaluation study in the initial phase of the project. Engineering calculations and a field test demonstrated the proposed interface level reduction did not affect quality of the water and the oil sampled at the separator outlet ports.
To reduce risk in the absence of detailed industry standards for engineering multiphase flow processes, a combination of numerical modeling, physical testing and process evaluation at the candidate plant was employed in the prototype design and engineering phase.
The fabrication and field installation of the prototype SID were outsourced to an engineering contractor. The vendor contract allowed close monitoring and oversight by a Saudi Aramco R&D team on all design, fabrication and installation tasks. Open communication with the contractor was very useful in the preparation of the industrial deployment of the technology.
Intelligent Field Infrastructure Embedded Cyber Security Protection
Authors: Al-Sharif Noor , Almadi Soloman 
Published: June 2014

Abstract
Cyber Security is an essential building block of the overall safety and integrity of Intelligent Field Infrastructure (IFI). This is driven by the rapid evolution from proprietary to open standard based solutions. Moreover, the IFI special purpose hardware and software is now increasingly moving to a common platform and from isolation to interconnection with the Enterprise networks and systems. This evolution has resulted in growing and previously unforeseen cyber security threats. Therefore, a closer look is required to ensure cyber security is embedded into existing systems and an integral part of workflows, policies, and skillsets of the workforce.
In this paper, the authors share critical review for the intelligent field cyber security risk, available solutions, and the systematic approach in weaving cyber protection into the end-to-end system. The outcomes result in actual enhancements by considering cyber security as integral part of the overall IFI. Best practices and guidelines improvements are also highlighted.
Design and Development of Non-aqueous Suspension for Suspending Variedsized Solid Particulates as a Conventional Diverter
Authors: Agashe Snehalata , Patil Prajakta , Raysoni Neelam , Pandya Nisha 
Published: June 2014

Abstract
Using solid particulate additives is becoming difficult because of strict health, safety, and environmental (HSE) concerns and green operation initiatives taken by operators. When solid particulates are used as additives for downhole treatments, they are generally batch-mixed into the gelled fluid as long as the viscosity of the fluid is sufficient to prevent settling of the particles. It is possible that solid particles could settle and block the blending equipment; hence, an additional blender is required at location to mix such solid additives so that the main or primary blender remains functional throughout the job for subsequent mixing of other treatment fluids. Using the additional blender requires additional logistics, man power, and associated costs to the operator. Therefore, it is usually recommended to use liquid additives in the field to help avoid problems associated with using solids and related additional equipment issues.
This paper describes the systematic approach used for the development of a non-aqueous suspension fluid for suspending varied-sized (8 to 40 mesh; ~2400 to ~400 μ particles of a particulate diverter with a specific gravity of 1.29 g/cm3. The developed suspension is stable at ambient temperatures for more than 30 days. It remains free flowing for more than 30 days, even at 40°F, and the solid particles do not settle, even at slightly higher temperatures, such as 100°F. The chemical score index (CSI) of the formulation is 120, which shows that the suspension is environmentally acceptable. Performance of the suspension was evaluated through core flow experiments with brown sandstone core samples, which indicated that the fluid containing the newly developed suspension of the diverter particles did not cause formation damage to the samples used.
Application of Best in Class Reservoir Management Practices in the Production Startup of a New Giant Field Development through Integration of Real Time Data: A Case Study
Authors: Al-Ghamdi Faisal A. , Al-Otaibi Majid H. , Abitrabi Ballan Abdel N 
Published: June 2014

Abstract
The development team successfully met the production startup milestone for a giant carbonate oil field. Central to the story of this significant accomplishment was the application of best-in-class reservoir management practices through integration of real-time data. In this field development, Saudi Aramco invested the necessary resources to bring Intelligent Field capabilities to its field operations. The challenge to fully utilize real-time data for prudent reservoir management practices prior to field startup and during the pre-water injection phase was met by the development team as described in this case study.
This paper describes the nature of the reservoir development and puts emphasis on the advantageous role that real-time data acquisition has played in allowing key reservoir management objectives to be met. The field is equipped with state-of-the-art data sensing and transmission capabilities. Examples of key reservoir management goals that will be discussed in this paper include maintaining reservoir pressure, water injection efficiency assessments, dynamic reservoir characterization process, real-time reservoir simulation model calibration process, and the concurrent release of field production/injection guidelines.
Isothermal Oil Compressibility Curve Crossing
Authors: Al-Marhoun Muhammad Ali 
Published: June 2014

Abstract
Oil compressibility above bubble point pressure is important in reservoir simulation, material balance calculations, design of high-pressure surface-equipment and the interpretation of well test analysis. Accurate calculation of oil compressibility is very important for reservoir evaluation.
The oil compressibility above bubble point pressure increases with increasing temperature and decreasing pressure, therefore, curves at the same pressure and different temperatures should not cross each other.
The conventional method of obtaining oil compressibility is from individual temperature measurement of pressure-volume data of constant composition expansion test. The oil compressibility determination involves pressure-volume function and its derivative at each temperature. This individual estimation with derivative calculation makes oil compressibility evaluation very sensitive to small derivative change that may lead to an invalid and non physical behavior of curve crossing.
This paper presents a special constrained multiple linear regression optimizations that ensures non-crossing of oil compressibility curves above bubble point pressure for multiple temperatures.
Comprehensive Reservoir Monitoring Program: Challenges, Design, Implementation, and Added Value in a Large Carbonate Reservoir
Authors: Al-Julaih Ali , Al-Dawood Naseem 
Published: June 2014

Abstract
Reservoir monitoring is an important aspect of prudent reservoir management to sustain productivity and achieve higher hydrocarbon recoveries. Monitoring is a process that comes in various forms, such as that of flood front advancement and reservoir saturation changes and quantification. Designing and implementing an effective monitoring program to track fluid advancement and quantify remaining oil saturation is a reservoir management best practice that ensures optimum sweep is achieved; and so is crucial for all fields, regardless of their state of maturity. The necessity for such programs becomes more critical as fields mature.
Reservoir saturation monitoring programs are usually faced with several challenges, including: mixed and low fluid salinity, tool limitations, borehole conditions and reservoir heterogeneity. Overcoming these challenges requires comprehensive programs that encompass adoption and integration of various derived saturation techniques.
This paper will discuss a reservoir monitoring program of a large carbonate field that has produced continuously for several decades. The monitoring program includes "key monitoring wells" in addition to drilling new evaluation wells that are strategically selected and are mostly located in well flooded areas. Time-lapse production and fit for purpose saturation logs are run in the existing wells, while extensive in situ measurements of fluid saturation are collected in the case of the new wells, to monitor saturation changes and track the movement of fluids.
The paper will also discuss the various methodologies adopted to address the aforementioned challenges. It will illustrate how the monitoring program has aided in tracking fluid movement, quantitatively determining fluid saturations and assessing sweep efficiency (Ed, Ev and Ea). In addition, the paper will show how the collected information was a catalyst in identifying sweet spots in flooded regions, and therefore guiding development activities for maximizing hydrocarbon recovery, especially from mature areas.
Optimizing Acid Stimulation Treatment Design in South Ghawar Power Water Injectors Wells
Authors: Tammar Hasan , Alkadem Mortada , Jandal Ahmed , Atayev Nurymyrat 
Published: June 2014

Abstract
Acid proved an efficient near wellbore skin damage removing agent in carbonate production and injection wells. Nevertheless, improving acid stimulation design is a continuous need in oil industry. Formation analysis logs for some of South Ghawar power water injectors have shown a significant amount of residual oil dominating the open hole interval. This phenomenon results in wells transmissibility reduction, which reflects negatively on injection rate.
A unique type of de-paraffin organic solvent was recently introduced to acid treatment design in South Ghawar PWIs to tackle injection impediment caused by high irreducible oil saturation. This solvent demonstrated a great capability in removing and flushing off residual oil, wax and asphaltene deposits in the reservoir matrix. Adding this solvent to pre-flush the rock enhanced the main acid treatment propagation into the reservoir, as well as water injection afterwards.
This paper presents the influence of the organic solvent on some of South Ghawar horizontal and vertical PWIs performance after acid treatment. It will also compare the injectivity of wells — with similar parameters and properties — that were acidized without adding this organic solvent in treatment. Differences in results due to modification of this product will also be discussed.
Advanced Well Completion Designs to Meet Unique Reservoir and Production Requirements
Authors: Jacob Suresh , Naimi Khalid M. 
Published: June 2014

Abstract
Well Completions design is continuously evolving to meet increasing requirements of down hole monitoring and control. The design of well completion has become more sophisticated as these requirements increase. Nowadays in the industry, it is rare to find a well completion that does not have some type of down hole sensor or inflow control. This paper presents overview of six different well completions designed to meet different reservoir and production requirements. Each of these design are integrations of existing and new technologies. The technologies presented in the paper range from inflow control devices and open hole packers placed in the reservoir section, multilateral junction systems, through permanent down hole sensors, surface controlled down hole valves and electric submersible pumps in the production tubing. The paper also discusses briefly the integration of the down hole equipment with surface control panels and SCADA communication systems. Different well types like oil producers, water injectors and artificial lift wells are discussed.