bluuebunny/crossref_metadata_2025_split huggingface dataset:
Novel Characterization of Thin Film at Reservoir Fluids Interfaces in Carbonates
Authors: Alotaibi M. B. , Cha D. K. , AlSaleh S. H. , Yousef A. A. 
Published: March 2019

Abstract
The salinity and ionic strength of injection water can make favorable impacts on wettability and oil recovery in different carbonate and sandstone reservoirs. The interaction mechanism between dissolved ions in injection water and reservoir fluids is a key ongoing research area. Most of these interactions occur at the thin film interfaces and so are considered one of the challenges in identifying and understanding the mechanisms. Conventional macro and microscopic laboratory techniques are commonly applied to determine contact angles, surface charges, and coreflooding to measure any incremental increase in oil recovery.
In this paper, advanced sum frequency generation (SFG) spectroscopy is utilized, for the first time, to characterize the chemical structures of molecules at the brine/crude oil interfaces. The change in the chemical structure is perceived with time at a broad wavenumber range from 1000 to 3900 cm−1. Distinct spectral signatures of oil components and water ions are detected for high salinity water (HSW), modified ionic strength water (MIW), and ions-free solutions.
The SFG data is also compared with the previous macroscopic wettability results to predict the components that are highly affected during waterflooding/enhanced oil recovery (EOR) processes. This study brings new insights about understanding the chemical structures at brine/crude oil monolayers and aqueous interfaces. The measured spectra at the interfaces along with the observed signal intensity trends are discussed in terms of composition and structure of organic and inorganic components. For example, SFG results from MIW oil interfaces and has higher spectral intensity at 2860 and 1700 cm−1 wavenumbers when compared with other brines used. These results exactly correlate with the C-H and C=O stretching bonds, which consider the key oil components at the interfaces.
The novelty of this interfacial study can give more ability to understand the reaction mechanisms as altering the ionic strength and salinity of the injection water. Such understanding is also crucial in optimizing the chemistry of injection water and its interaction with oil components and carbonate rock to ultimately alter wettability toward water-wet.
New Model for the Elastic Modulus for Saturated Porous Carbonate Rocks
Authors: Ismail Marwah AL , Morgan Frank Dale 
Published: March 2019

Abstract
The wave velocity is defined theoretically by the Newton-Laplace equation, which relates the wave velocity, V, to the square root of the ratio of the elastic modulus, M, and density, ρ. Therefore, the equation indicates that the velocity is inversely proportional to density. However, the in-situ field measurements and laboratory experiments of compressional wave velocity through different rocks show otherwise, where the velocity is directly proportional to approximately the 4th power of density as stated by Gardner's numerical approximation. To clarify the apparent contrast between theory and observations, a new expression for the elastic modulus, M, is derived using Wyllie's time average equation and the Newton-Laplace equation. The new derived expression of the elastic modulus, M, provides dependence of M on density to approximately the 9th power, which subsequently results with the observed dependence of velocity on the 4th power of density. In addition, Gardner's equation is modified to accurately obtain the velocity over range of densities (from 1 g/cm3 to around 3 g/cm3). The findings are tested on real velocity and density well-log data. The results validate the derived expression of the elastic modulus as well as the generalized form of Gardner's equation.
Computational Fluid Dynamics CFD Evaluation of Laminar Flow of Bitumen-in-Water Emulsion Stabilized by Poly Vinyl Alcohol PVA: Effects of Salinity and Water Cut
Authors: Alade Olalekan , Al Shehri Dhafer , Mahmoud Mohamed , Sasaki Kyuro , Sugai Yuichi 
Published: March 2019

Abstract
Applications of oil-in-water emulsion (O/W) emulsification technology in enhanced recovery and pipeline transportation of heavy oil can be limited by several factors including salinity of the reservoir or process water, process temperature, and water cut. In this investigation, laminar flow of O/W was simulated in a pipeline to investigate the effect of salinity of aqueous phase (NaCl) and water cut on flow characteristics of the fluid. The case was simplified by considering the O/W as a stable, pseudo-homogeneous, single-phase fluid within the conditions operated. Pertinent to the objective of the study, at flow reference temperature, Tref = 30oC, the pressure drop at 30% water cut was 931Pa compared to 84.6 Pa at water cut of 50% (reference working fluid without NaCl). In contrast, the pressure drop was 239Pa, 142Pa, 124Pa, and 82.9Pa at 70000ppm, 40000ppm, 20000ppm, and 10000ppm salinity in the aqueous phase, respectively. In addition, the maximum dynamic viscosity imposed by the fluid, was ≈81000cP at 30% water cut compared to ≈14000cP from the reference fluid. The dynamic viscosity obtained from 70000ppm salinity content was ≈34000cP. Moreover, the results confirm facile application of emulsification technology for pipeline transportation of bitumen from large reduction in pressure drop (99%) regardless of the water cut and salinity.
Metal 3D Printing Applications in the Oil & Gas Industry
Authors: Burns Madison , Wangenheim Christoph 
Published: March 2019

Abstract
Additive Manufacturing (AM) is a set of technologies that has historically found fertile applications in the aerospace and healthcare industries, while adoption in the oil and gas (O&G) sector has progressed slowly. Nonetheless, AM is reaching maturity in this industry as well, allowing for significant innovation. This paper describes how AM has been integrated within the value chain of a major oilfield supplier, highlighting specific peculiarities for each of its business segments. "Fullstream" activities of the oilfield supplier cover the entire O&G value chain, from the exploration of reservoirs and production (upstream) to the transportation and storage of hydrocarbons (midstream), as well as refining and industrial power processing (downstream). AM technologies in this company were originally deployed for rapid prototyping, but they have matured as strategic manufacturing pillars to address the maintenance of equipment of all industry segments within the company. Several manufacturing methods within the AM landscape can be deployed, depending on the technical requirements of the components and the environment in which they operate. O&G equipment end users face several challenges when dealing with spare parts management, such as performance, total cost of ownership, procurement time, inventory levels and obsolescence. From an OEM standpoint, serving a wide fleet with a variety of products and their different versions (with an unpredictable and unstable demand) is challenging. AM is the tool that enables a new way to serve such an installed fleet. The company has already experimented with several applications regarding obsolete spare parts re-introduction through AM, gaining strong benefits (50% +) in terms of cost and procurement time reduction. Consequently, it is important to continue adopting AM to deliver faster outcomes for the customer at first. This, in turn, fosters the development of sound knowledge and references that can then be used to develop further solutions and value propositions for the customers.
Overview of Carbonate Rock Types in the Middle East
Authors: Dernaika Moustafa , Mansour Bashar , Al-Jallad Osama , Koronfol Safouh 
Published: March 2019

Abstract
The complexity and diversity of carbonate reservoirs necessitate having a consistent approach in defining rock types. Core data on a rock-type basis are required as input for modelling reservoir performance. The objectives of this paper are to provide detailed understanding of the controlling factors in rock typing and to develop a unique rock-typing approach that can apply to carbonate reservoirs in the Middle East region.
More than 1,000 core plugs were studied from seven different carbonate reservoirs. The plugs were carefully selected from 15 wells to represent the primary property variations along the cored intervals. The data set available included laboratory-measured helium porosity, gas permeability, thin-sections, and high-pressure mercury injection capillary pressure (MICP). Plug-scale X-ray computed tomography (CT) imaging was acquired to help ensure the samples were free of induced fractures and other anomalies that can affect the permeability measurements. Rock textures were analyzed in the thin-section photomicrographs and were classified based on their content as grainy, muddy, and mixed. Special attention was given to the diagenesis effects, mainly compaction, cementation, and dissolution. Porosity was defined as interparticle, intercrystalline, moldic, intraparticle, or vuggy.
The texture information was plotted in the porosity-permeability (poro-perm) domain and was determined to produce three distinct poro-perm relationships. Each texture provided an unique poro-perm trend. Rock types were defined on the poro-perm trends and showed a strong link to diagenesis and capillary pressure (Pc). For each poro-perm trend, the rock types were distinguished by detailed Dunham textures and different degrees of diagenesis. The detailed textures and diagenesis were correlated reasonably well with the poro-perm data and MICP, hence providing robust rock types.
A new rock-typing approach was successfully applied in different carbonate reservoirs. The poro-perm cloud from the different reservoirs was resolved into trends and ranges based on textures and diagenesis. Common controlling factors were observed, which can help produce data analogues along more reservoirs in the region. The texture-diagenesis-based rock types provided more insight into the effects of geology on fluid flow and saturation. Geological textures were derived along the cored intervals and provided upscaling options for permeability and rock types in the reservoirs.
The Evolution of Light Oil Thermal Pilots in Mauddud Reservoir from Lab, Simulation to Pilot Scale
Authors: AL-Muftah Ali , Mansoor Mohamed , AlOwainati Ebrahim 
Published: March 2019

Abstract
The Light Oil Steam Flood (LOSF) is proposed to increase the recovery from Mauddud reservoir in Bahrain Field. Mauddud has been on gas injection since 1938, yet residual oil saturation is still high in the gas cap due to its oil wettability. Several core lab studies were conducted confirming the high oil saturation in the gas cap. Steam flood core lab experiments were conducted recently and confirmed the residual oil saturation could reach to less than 10%. The thermal pilot project in Mauddud has gone through the following stages: The first pilot started in 2013 and operated for 2.5 years: It has one horizontal well in the gas cap, one vertical producer, four vertical injectors with three Temperature Observation Wells (TOWs) clustered around one of the injectors.First pilot performance was assessed and confirmed in reducing the residual oil in the gas cap by distillation and wettability alteration.Second pilot was designed and initiated in 2016 to assess the economic viability for full field expansion.
Throughout these stages, production monitoring, logging, core studies and simulation studies have been carried to understand the LOSF mechanisms to increase Mauddud recovery from the gas cap.
This paper presents the evolution of pilot design concepts and simulation of the thermal recovery in Mauddud. It also study and assess the well configurations and pilot operating strategies designed for the thermal pilots. A sector model was constructed and calibrated, then used to select a well concept for the LOSF pilots. Seventeen different pilot concepts were considered during the selection process. The well configuration and operating strategies were driven to observe a quicker steam response in the first pilot. A number of sensitivities were conducted to develop a better understanding of the effects of the various reservoir factors.
A comprehensive study was then carried out to recommend a phase development approach for full-scale field development and establish a methodology for a full-field LOSF forecast. Full Field compositional model was built in thermal reservoir simulator and was then successfully history matched with seven components equations of state (EOS). A phased development approach was then proposed for full-scale field development. The initial development will focus on the mid-dip areas with higher remaining oil saturations and a thicker oil column. After establishing production in the mid-dip flanks, development could proceed to the crestal areas, which have lower oil saturations and would likely result in higher steam/oil ratios (SORs).
Well Success – An Interdisciplinary Evaluation Parameter
Authors: Gamperl Florian 
Published: March 2019

Abstract
The paper presents an approach that integrates various success criteria that the different disciplines involved in planning a well have in mind during the planning phase. Apart from purely economic factors, the "value of information" is considered in this approach, which requires a "proxy". An approach has been developed based on a 26 well drilling campaign, which integrates various aspects under which a well can generate value for a company, into a single "well success indicator". This key performance indicator (KPI) flexibly weighs various factors representing the different disciplines involved in planning a well; the weight factors can easily be adjusted to the needs and requirements of companies or projects. The paper will discuss the approach taken to develop the system and the prerequisites for applying the system to any well.
While in some wells, the evaluation based purely on economic criteria like additional recoverable oil or increased production rates, yields the same "success" as with the more detailed approach. However, for most wells, significant differences can be observed. A factor is that the usual approach does not consider information in the same way – although that can reduce the risk for future wells, and as such save money. Even if this information is not translated into monetary value, it can be appreciated as a part of goals set by each discipline. If such goals are well-defined, they can be used to evaluate the well success – which is more than just the project economics. It can also be seen that poorly chosen weighting factors, can distort the view on a project significantly.
The Impact of Automated Fault Detection and Extraction Technology on Seismic Interpretation
Authors: Al-Maskeen AbdulMohsin A. , Ali Sadaqat S. , Khan Muhammad 
Published: March 2019

Abstract
3D wide azimuth seismic data plays a vital role in fault interpretation, which has significant importance during exploration and development stages. Interpreting faults in 3D seismic data is one of the most time consuming and challenging process especially when dealing with poor quality seismic data. This paper provides a complete workflow and example of its application from seismic pre-conditioning to fault detection and extraction automatically based on published concepts by Dave Hale. With recent advancement in computer technology, multi-threaded algorithms and data driven methodologies, geoscientists can automatically detect and interpret virtually all discontinuities in seismic data in an efficient manner.
This workflow involves random and coherent noise suppression, seismic likelihood attributes generation to enhance the discontinuities, detect faults and extract them from thinned fault likelihood volume. Unlike other fault tracking methods that use local seismic continuity attributes, such as coherency, this automated method incorporates aspects of Hale's fault-oriented semblance algorithm, which highlights fault planes with unprecedented clarity.
This methodology has been successfully applied on complex faulted reservoirs. It contributes to the extraction of detailed discontinuity information (minor and major) from 3D seismic data. The traditional manual interpretation step that follows the detection of faults was time consuming and error prone. Automated fault interpretation improves the fault tracking accuracy, consistency and significantly reduces fault interpretation time in prospect generation. This workflow will optimize and reduce uncertainty associated with the seismic fault interpretation process.
Modeling and Simulation to Produce Thin Layers of Remaining Oil Using Downhole Water Sink Technique for Improved Oil Recovery. A Case Study in Greater Burgan Field.
Authors: Al-Fadhli Wuroud , Kurma Ravi , Kovyazin Dmitry , Muhammad Yaser 
Published: March 2019

Abstract
The case study describes a modeling and simulation study of an inverted ESP completion to address three fundamental objectives. A) Increasing the ultimate oil recovery in the massive sands of Cretaceous age in Greater Burgan field by managing water production B) Mitigating the rapid water coning conditions in this high permeable water drive reservoir and C) Designing an optimal operating strategy with Downhole Water Sink (DWS) to control water production and manage well performance. A 2×2km sector was carved out from the full field geological model with 12 wells including the study well. The study well was producing at high water cut at the time of the study. All static properties were updated, and the model was history matched for production, pressure and saturation. Several sensitivity runs were performed, and prediction scenarios were run for 5 years to observe well production behavior in time. The well model was setup with an inverted ESP between straddle packers to produce water from below OWC and inject into bottom reservoir with a production string above to produce from the oil zone. This setting ensured a reverse oil cone being generated from below OWC in the reservoir under production. The aquifer model was finite in size enabling bottom water influx. Simulation results showed that implementation of DWS technology made the water production reduced by 18% during five years with an increase in oil production of nearly 25% in the study well. To maintain continuous well offtake rate, a range of water rates to be produced and injected to bottom reservoir have been studied. Several iterative runs were made to investigate the best completion interval and injection & production rates. The profiles of oil water interface near well bore indicated good reduction in the cone height as compared to normal completion. The results also showed significant improvement in oil recovery within the drainage radius of the well from the simulations. Simulation results provided good understanding of the saturation change near well bore area under different production rates. Prediction runs were made for sustainable oil production under natural flowing condition and the conditions to switch over to production under artificial lift. Production of thin layers of remaining oil from within high permeable massive Burgan middle sands has been a high concern due to very high water cuts because of coning. The study results have provided encouraging option with DWS technique to improve recovery from the reservoir.
Laboratory Evaluation of Weighting Materials for Ultra-High Density Oil-Based Drilling Fluids in Ultra-HPHT Wellbore Applications
Authors: Li Qinghui , Zhu Jinzhi , Li Shaoxuan , Zhang Shaojun , Hisham Nasr-El-Din , Ren Lingling , Li Jiaxue , Al-Mujalhem Manayer 
Published: March 2019

Abstract
Global energy demand has driven the petroleum industry to develop hydrocarbon resources from extremely harsh formations which contain ultra-high pressure and temperature (HPHT) reservoirs. Ultra-high density drilling fluids are critical to successful drilling and completion practices in all of these wells. In this paper, potential weighting materials were systematically evaluated and screened to accomplish an ultra-high density oil-based drilling fluid system (19.62 to 22.12lb/gal) aimed to utilize in ultra HPHT conditions (&gt;30000psi and &gt;410°F).
Several potential high-density weighting materials were evaluated in the laboratory conditions. Basic properties (pure density, particle size/distribution, surface area etc.) were evaluated and compared. Special treatments were conducted to optimize the properties of weighting materials. HPHT filtration tests under static and dynamic conditions were conducted at higher than 410°F and 300 psi. Real cores with an average porosity of 19% and an average permeability of 50 mD were used in the filtration tests. Rheological properties, sag tendency, the volume of filtrate, and the filtrate cake characterization of oil-based drilling fluids were measured before and after heating at 410°F for 16 hours.
Results revealed that ultra-micro manganese and ilmenite complex after suitable surface treatment could act as an ideal weighting material than ultra-pure barite or other materials, which could fail in rheology and sag controlling measurement with such high temperature and density. The viscosity and filtration analysis confirmed the stability and reliability of this novel ultra-high density oil-based drilling fluid.
This study developed a challenged drilling fluid system under critical testing states, as well as established a systematical laboratory evaluation and screening procedure of weighting materials for ultra-deep wells and contributed recommendations on how to utilize it in the fields.