bluuebunny/crossref_metadata_2025_split huggingface dataset:
Acidizing Treatment Design Assessment Based on Dolomitic Field Core Testing
Authors: Santos Sarai , Salazar Munive Angel , Hernandez Del Angel Everardo , Villaseñor Omar , Guzman Almazo Jose Luis , Hernandez Vulpes Dulce , Beuterbaugh Aaron M. , Reyes Enrique Antonio , Squires Scott , Campos Katya 
Published: February 2022

Abstract
Fields in offshore Mexico present different challenges to maximizing resource recovery due to the reservoir characteristics and completion configurations. Acidizing of high temperature (HT) dolomitic reservoirs (290 °F/143 °C) in the maritime fields represents the primary stimulation option due to existing well parameters restricting treatment designs to matrix rate conditions.
Acidizing treatments are typically based on HCl and organic acids and for the first time a multifunctional, low viscosity, retarded HCl acid is also available. Laboratory wormhole tests were conducted for matrix injection but also in a pseudo-acid fracture condition (split-core) in order to establish feasibility for future stimulation designs. Three acid blends were used, a blend of organic acids (OA), a mixture of HCl and organic acid (HA), and a polymer free retarded HCl acid (HRMA).
The cores tested correspond to a particular well and X-ray Diffraction (XRD) analysis confirms it is &gt;98% dolomite. CT imaging corroborates the heterogeneous permeability due to primary and secondary porosity systems (5% – 10% and 10% – 15%). The pore volume breakthrough of each acid blend was determined for two cores of similar porosity under same constant injection rate. Results indicate the organic acids blend (OA) can have better injectivity when flow rate is much higher than the HCl/Organic acid (HA) blend. A core with 10X lower permeability (0.1 – 0.5 mD) was tested with new Retarded HCl acid (HRMA) using same injection rate as the other acid blends. Results indicate that Retarded HCl (HRMA) does not cause core facial dissolution under unoptimized injection rate. The wormhole patterns generated for the HCl/Organic acid (HA) blend show good distribution and for Retarded HCl (HRMA) show enhance acid containment (less ramification). Both HCl acid blends (HA and HRMA) are suitable for dolomitic acidizing under different injection rates, while the purely organic acid blend is more adequate for high rate injection.
Notably acidizing of dolomitic reservoirs can be highly efficient under optimized conditions and future work with non-retarded and retarded acids can systematically drive pumping engineering designs. The Retarded HCl acid (HRMA) has multifunctional properties including scale inhibition and lower HCl reactivity.
Improving Fluid Loss Control During Well Intervention; A Case Study on the Use of Innovative Salt System
Authors: Hussein Mahmoud , Al-Rashedi Hamad , Al-Naqi Ahmad , Gonzalez Santiago , Erhamah Abdulaziz , Najaf Reeham , Malik Satinder , Bosilca Dan , Ali Mohamed , Tresco Kim , Luyster Mark 
Published: February 2022

Abstract
Kuwait heavy oil development target reservoir is a shallow, sub-hydrostatic and unconsolidated sandstone with relatively high porosity and permeability.
Due to nature of this reservoir, well intervention operations in North Kuwait Heavy Oil Asset exhibit a higher risk of significant fluid loss that causes wellbore impairment, incremental operational costs, excess brine volume usage, and more importantly a significant impact on production deferment. The latter is due to formation damage and the time required to produce the completion fluid that is lost to the reservoir during any well intervention.
The objective of using a cost-effective and less non-damaging fluid is achieved by the application of a novel customized salt system that was successfully trialed in the field.
A systematic research was employed to find a suitable product/system that could be used in sub- hydrostatic conditions, able to effectively control fluid loss while retaining as near the original permeability.
This new system and subsequent formulation adhered to the following criteria:
Readily available Cost effective Easy to formulate and pump Easy to circulate out No long-term formation damage thus retaining original formation permeability
The success of this fluid loss control material is indicated by a constant fluid level at surface after application thereby confirming its effectiveness in meeting the desired objectives.
This salt system application was successfully field tested, and the results were satisfactory. During well intervention operations, the system effectively arrested fluid loss as confirmed by the fluid level measured at surface. Post operation, the well was brought back immediately to its original rate thereby confirming little to no permanent reduction to reservoir permeability.
Historically, during well interventions in Kuwait Heavy Oil field, dynamic loss rates measured were in the 100 to 120 bbl per hour range. Post application of this salt system showed fluid loss rates ranging from 3 to 4 bbl per hour. To date no post acid stimulations were required to restore well production to original levels. This system was readily adapted for thermal application and compatibility with existing fluids, good bridging characteristics, as well as flow-back enhancement. This approach eliminated additional AFE costs by minimizing dynamic losses.
Uncertainty Driven Formation Damage Control Using Analytical Technique
Authors: Andryushchenko Aleksei , Ghalambor Ali 
Published: February 2022

Abstract
The aim of this work is to develop an analytical technique for characterizing formation damage.
The oil reservoir of the East Siberian Yaraktinskoe field suffers from salt and organic scales precipitation leading to skin damage. Besides, injection water has sulfates, which precipitate as gypsum in the near wellbore area of production wells and at bottomhole. Historically pressure build-ups (PBU) were used to characterize the evolution and extent of the damage. The use of PBUs leads to the shut in of production. Additionally PBUs in the reservoir provide conclusive results in no more than 22% cases. Based on inconsistent results from PBUs and their cost in production losses, it was of interest to find a better and preferable technique for formation damage control using existing data.
The result of that initiative is analytical technique that provides dimensionless productivity index (Jd) range monitoring over time, Jd range comparison to the technical potential and identification of the performance gap range. By identifying the performance gap range, stimulation actions are ordered reestablishing oil production, productivity index (PI) and Jd.
The technique is based on transmissibility (kh/µB or T) model derived from Kamal and Pan study (2010) and reservoir pressure (Pres or P) model. Stochastic part of the technique is provided by T and Pres error functions. The functions are probability distribution functions (PDF) derived from comparison of the modeled T and Pres with well test measured historical values. Using this T and Pres models and historical data of liquid rates and bottomhole pressures (BHP), we can calculate current and historical Jd, Jd drop relative to historical performance or potential and oil rate potential increment with uncertainty margins (10th, 50th and 90th percentile or P10-50-90). The margins are calculated from 10000 stochastic iterations of T and Pres within the PDFs of their error.
The technique has enabled to find 14 stimulation candidates during 6 month of use. Overall, 15 stimulations were implemented since one well was stimulated twice. Ten of 14 stimulations increased oil production rate by 4161 bbl/day. Five stimulations were economically unsuccessful due to inappropriate stimulation technology implementation. The technique shows acceptable uncertainty level to make efficient and appropriate decisions for the appropriately chosen stimulation technology. Modeled P50 PIs have good match with more than 85% correlation with well test measured PIs after economically successful stimulation.
New analytical technique is presented here, which can be utilized as an automatic process without repeating well tests for routine generation of accurate stimulation plan with numerical assessment of success probability and anticipated oil rate increment uncertainty range. Realization of stimulation potential is simplified to the task of appropriate treatment technology selection and implementation for the candidates from the rating.
Specially Tailored Reservoir Drill-In Fluid and Acid Precursor Technology with Applicability in Ultra Deepwater Gulf of Mexico Wells
Authors: Granger Brittany , Harton Joshua , Detiveaux Christopher 
Published: February 2022

Abstract
The Gulf of Mexico (GoM) presents an array of complex challenges, including ultra-deepwater depths, narrow pressure window environments, low permeability, and elevated temperature zones. Operators in the GoM frequently experience highly reactive, unstable shales while drilling long, heterogenous open hole lateral wells. While traditional Reservoir Drill-in Fluids (RDF) and breakers are well known for use in production wells, the filter cake cleanup can often be non-uniform, corrosive to completion assemblies, and result in variable drawdown. This disparity in pressure drawdown across the reservoir section can ultimately result in the creation of positive skin damage. Injector wells offer a more extreme scenario in comparison to production wells because no flowback occurs, which can make it more difficult to deliver sustainable uniform injection. The solution to these challenges lies in the development of RDF and breakers specifically tailored to provide uniform, time delayed coverage, minimal corrosivity, and effective removal of the RDF filter cake. In order to successfully maximize injection and maintain performance for the scope of the field life, an RDF was customized in tandem with an optimized, delayed-release filter cake breaker to limit formation damage and provide complete uniform filter cake removal. This paper will discuss how the learnings from Eastern Hemisphere operational activities directed at optimizing treatment designs for more difficult injector wells can be tailored for efficient use in the GoM. Results from laboratory testing and global field applications of the new RDF and breaker designs will be presented, as well.
Reversible Fluids and Mud Breaker Technology Outperforms Productivity and Injectivity in West Africa–Fit to Purpose and Designed for Success
Authors: Eyaa Allogo Clotaire-Marie , Allias Benoit , Tayebi Redda , Baraque Antoine , Lansot Jean Yves , Diogo Jose 
Published: February 2022

Abstract
Lessons learned in Moho-Nord field Congo improved well productivity and injectivity, from Miocene formation. Due to the type of drill-in fluid used in the initial development phase of the field, the skin factor showed extremely high values, above 150. The values dropped to near 50 after remediation and stimulation operations. Productivity and injectivity rates were significantly poor and did not meet the targets.
To mitigate these issues, the most suitable fluids for drilling, completion and removing the filtercake for a horizontal open hole standalone completion were required. Fluids were identified by an extensive laboratory study. The selection was based on the reservoir characteristics and sand control completion type. It was also based on review of past experiences from the original project phase, and continuous discussion between operator and the fluids provider. Changes were made to improve practices during the field implementation.
One reservoir drill-in fluid (RDF), a reversible invert emulsion (RIE) non-aqueous base mud (NABM) system and two filtercake breaker systems were selected and implemented in the field. The RIE showed suitable properties required for NABM drilling. It also demonstrated properties of easier filtercake destruction when exposed to lower pH breaker fluids. Its filtercake did not need surfactant/solvent pills to change the wettability of the solids in the filtercake which notably simplified the borehole cleanup operation. The improvement occurred throughout the second and third phases of the field development. The ameliorations were measured through skin value, production and injectivity rates and initial flow initiation pressure. Values were compared against initial targets. As an example, the skin value went from 150 in phase one to less than 5 in phase three. No acid stimulation was required in any of these wells, providing a huge cost saving for the operator. The combination of the fluids selected, and improved drilling and completion practices led to skin values for most between 0 and 3. The productivity and injectivity outperformed and surpassed expectations.
Knowledge gained from the study re-established the importance of selecting the suitable fluids systems and using best in class drilling and completion practices. This paper summarizes upfront fluid design requirements and fluids management procedures implemented during drilling, completion and filtercake breaker placement to ensure safe and successful open hole completions.
DNA Tracer Technology Applications in Hydraulic Fracturing Flowback Analyses
Authors: Asadi Mahmoud , Blair Tyler , Kuiper Ben , Cunningham Bruce , Shamburger Tim , Looyenga Brendan , Morales Rogelio 
Published: February 2022

Abstract
A new and robust tracer technology, based on Nano-sized encapsulated silica DNA sequences is presented. This cutting-edge technology enables a bond of each DNA sequence to a magnetic core particle and encapsulates it with silica. Therefore, one can have infinite sequences of DNA tracers. Each DNA tracer, with its identity signature, can be easily identified and characterized with no interferences. Unique chemistry makes these DNA tracers, either water-wet or oil-wet. The water-wet tracers can be used in hydraulic fracturing to precisely and accurately analyze flowback, both qualitatively and quantitatively. The oil-wet tracers can be used in evaluating the source and quantity of oil production in hydraulic fracturing. In-depth laboratory testing indicates that these tracers, unlike current industry used chemical tracers, are stable at high temperature, do not react with formation mineralogy to form reservoir rock plating, do not partition, and do not disintegrate over time. These tracers are injected in the liquid-laden slurry at very low concentrations and can be detected at parts per trillion.
Numerical Modeling of Waterflooding Experiments in Artificially Fractured and Gel Treated Core Plugs by Embedded Discrete Fracture Model of a Reservoir Simulation Toolbox
Authors: Kaya Onur Alp , Durgut Ismail , Canbolat Serhat 
Published: February 2022

Abstract
The fluid flow dynamics of the matrix and fractures are significantly different from each other. Fractures are high-permeability flow channels that serve as the main flow units. On the other hand, the Matrix takes up the majority of the reservoir volume and is generally regarded as the main storage unit. The primary goal of this research is to investigate numerically the effects of fractures and polymer gel treatment on oil recovery during waterflooding of artificially fractured core plugs. In this study, the MATLAB Reservoir Simulation Toolbox (MRST) was used for the numerical solution. Different numerical models were developed using MRST to describe three main cases: non-fractured core plug, fractured core plug, and polymer gel treated core plug. Following the creation of the physical models, 2 PV water was introduced into all core plugs. Oil recovery and water saturation profiles vs. time plots were obtained. The standard Buckley-Leveret solution is utilized to evaluate the numerical model, and the fractures are modeled using the Embedded Discrete Fracture Model (EDFM). The results of the simulations were compared with the results of the experiments. In the experiments, results were recorded after 2 PV water injections. For the polymer gel treated core plugs, 2 PV more water was injected after the polymer gel operation. same injection volumes as used in the MRST model. For an artificially fractured core sample, initial oil recovery was measured as 28.57% experimentally and 28.87% with MRST. Then polymer gel was applied to the core plug, increasing the oil recovery to 42.85% experimentally and to 40.83% with MRST. Similarly, before and after polymer gel operation, mean water saturation was measured as 58.34% and 66.5%, respectively. MRST results showed mean water saturation of 58.38% and 65.45%. It is clear from both numerical and experimental models that the existence of fractures decreases the overall hydrocarbon recovery. Polymer gel treatment decreases fracture permeability, resulting in a more uniform sweep and increased overall recovery. Additional oil recovery was observed after polymer gel treatment. Besides, polymer gel treatment of the matrix is also efficient for increasing the recovery and leads to the same results. Moreover, the effects of the fracture aperture and fracture permeability on the recovery were also investigated. Fracture aperture directly impacts the recovery of the low aperture values when the permeability is constant. Similarly, permeability directly affects recovery for high values when the aperture is constant. Finally, the results showed that experimental and numerical findings are significantly close to each other for all non-fractured, fractured, and polymer gel-treated cases.
Protective Effect of Phytogenic based Additives in Enterotoxigenic Escherichia Coli Challenged Piglets
Authors: Caprarulo Valentina , Turin Lauretta , Hejna Monika , Reggi Serena , Dell'Anno Matteo , Riccaboni Pietro , Trevisi Paolo , Luise Diana , Baldi Antonella , Rossi Luciana 
Published: February 2022

Abstract
Post Weaning Diarrhea (PWD) is the most important multifactorial gastroenteric disease of the weaning in pig livestock. Phytogenic (PHY) natural extracts are largely studied as alternatives to antibiotic treatments in combating the global concern of the antimicrobial resistance. The aim of this study was to evaluate the protective effect of innovative phytogenic premix with or without short and medium chain fatty acids (SCFA and MCFA) in O138 E. coli challenged piglets. Twenty-seven weaned piglets were allotted into four groups receiving different diets according to the following experimental doses: PHY1 (n=7) fed basal diet supplemented with 0.2% of phytogenic premix, PHY2 (n=7) fed basal diet supplemented with 0.2% of phytogenic premix added with 2000 ppm of SCFA and MCFA. After 6 days of feeding experimental diets, animals were challenged (day 0) with 2x109 CFU/dose of E. coli and CTRL group fed basal diet was divided at day 0 into positive (CTRL+; n=6) and negative control group (CTRL-; n=7). Body weights were recorded at -14, -6, 0, 4 and 7 days and the feed intake was recorded daily. E. coli shedding was monitored for 4 days post-challenge by plate counting. Fecal consistency was registered daily by a four-point scale (0-3; diarrhea >1) during the post-challenge period. Tissue samples were obtained for gene expression and histological evaluations at day 7 from four animals per group. Lower average feed intake was observed in CTRL+ compared to PHY2 and CTRL during the post-challenge period. Infected groups showed higher E. coli shedding compared to CTRL- during the 4 days post-challenge (p<0.01). PHY2 showed lower frequency of diarrhea compared to PHY1 and CTRL+ from 5 to 7 days post-challenge. No significant alterations among groups were observed in histopathological evaluation. Duodenum expression of occludin tended to be lower in challenged groups compared to CTRL- at 7 days post-challenge (p=0.066). In conclusion, dietary supplementation of PHY plus SCFA and MCFA revealed encouraging results for diarrhea prevention and growth performance in weaned piglets.
The chemical chaperon 4-phenylbutric acid improves cardiac function following isoproterenol-induced myocardial infarction in the rat
Authors: Vatankhah Fatemeh , Garjani Alireza , Vaez Haleh 
Published: February 2022

Abstract
Purpose 4-phenyl butyric acid (4-PBA) is a chaperone-mediated autophagy (CMA) inducer, which eliminates unnecessary and damaged cellular components through lysosomal enzymes. It could reduce misfolded and unfolded proteins produced after myocardial infarction (MI) and can improve cardiac function. We aimed to investigate the effect of 4-PBA on isoproterenol-induced MI in the rat. Methods Isoproterenol (100 mg/kg) was injected subcutaneously for two consecutive days simultaneous with an intraperitoneal (IP) injection of 4-PBA at 20, 40, or 80 mg/kg with 24-h intervals for five days. On day 6, hemodynamic parameters, histopathological changes, peripheral neutrophil count, and total antioxidant capacity (TAC) evaluated. The expression of autophagy proteins measured by using western blotting. 4-PBA significantly improved post-MI changes in hemodynamic parameters.Results Histological improvement found in 4-PBA 40 mg/kg (P<0.05). The neutrophils count in the peripheral blood significantly decreased in the treatment groups compared with the isoproterenol. Furthermore, 4-PBA at 80 mg/kg significantly increased the serum TAC compared to isoproterenol (P<0.001). Western blotting results showed a significant decrease in the P62 level (P<0.05) of 40 and 80 mg/kg 4-PBA treated groups.Conclusion This study demonstrated that 4-PBA could have a cardio-protective effect against isoproterenol-induced MI, which can be due to the modulation of autophagy and inhibition of oxidative stress. Obtaining effective results in different doses shows the need of optimum degree of authophagic activities in cells.
Design of an industrial Photovoltaic-Driven Reverse Osmosis (PV-RO) Plant in Bahrain
Authors: Fardan Ali , Albuflasa Hanan , Sultan Amin , Davies Philip 
Published: February 2022

Abstract
Renewable energy-driven desalination is a viable solution for such an energy-intensive industry. In the gulf cooperation council (GCC) region, where the largest desalination plants worldwide are accommodated, fossil fuels exhibit a real dilemma. Nonetheless, the region features an abundant solar energy resource. This work contributes to the collective efforts for shifting the conventional fossil fuel-dependent desalination associated with a high carbon footprint toward an eco-friendly model by integrating photovoltaic (PV) technology.Within this frame, an industrial brackish water reverse osmosis (BWRO) plant went under energy analysis to set the appropriate PV-driven RO design. Finally, a grid-connected design was simulated by Helioscope and PVsyst software to integrate half-cut cells PV modules (460 Wp) on the rooftops of three buildings.The results showed that 525 kW AC power (DC/AC ratio≈ 1.2) could be achieved with a specific yield of 1258 kWh/kWp, and an overall performance ratio of 79.1%, representing around 786 MWh annually.