bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovation on Street Food Products (Instant Porridge and Cookies) Based on Fortified Patin Fish Protein Concentrate with Red Palm Oil and Encaptulated Oil Fish
Authors: Dewita Dewita , Syahrul Syahrul , Desmelati Desmelati , Lukman Suardi 
Published: September 2016

<p>This research aimed to establish innovation on street food (instant porridge and cookies)<br />from Patin Fish Protein Concentrate fortified by blending red palm oil and encaptulated patin<br />fish’s oil. The Encaptulation was conducted by blending of red palm oil and patin fish’s oil using<br />spray dryer. The blending was consisted of three combinations namely 50 : 50 (A1), 40 : 60 (A2)<br />and 60 : 40 (A3) for ratio between red palm oil and patin fish’s oil. The best combination’s results<br />was fortified into street food (instant porridge and cookies). The blending was tested by measure<br />yield, fat and fatty acid profile. Moreover, organoleptics and proximate tests were carrie out for the<br />best treatment of blending in instant porridge and cookies. The results show that encaptulated<br />yield reached 55 % that rise from A1 treatment as the best treatment with fat content of 17.26%.<br />Profile of unsaturated fatty acid especially fatty acid omega 9 from blending fish oil and palm oil<br />was 59.29%. The number of fatty acid omega 9 was higher than saturated fatty acid which was<br />18.56%. Furthermore, based on organoleptic tests of instant porridge and cookies using under five<br />year children respondents, it was proven that 93% of children was like the products. Proximate </p><p>analysis of instant porridge revealed that protein content was 11.04 %, water content was 5.03%,<br />fat content was 1.92 % and ash was 0.64 %. However, proximate analysis showed that cookies<br />owned protein of 9.11%, fat of 17.03% , water content was 3.93% and ash of 1.38%.<br />Keywords : Encaptulated fish, street food, patin fish protein concentrate, palm oil</p>
Dermoscopy of a non-pigmented eccrine poroma
Authors: De Diego Maria Clara , Ruiz Beguerie Julieta 
Published: September 2016

<p>Eccrine poroma is a benign adnexal tumor arising from cells of the outer layer of the acrosyringium and upper dermal eccrine duct. It generally appears as a solitary, slow growing, sessile, pink-to-red and well-circumscribed papule, plaque or nodule. It is usually located on the palms and soles but it may also develop on other locations. Its clinical appearance can resemble other types of tumors such as hypo- or amelanotic melanoma. Dermoscopy has improved the evaluation of skin tumors. In the case of eccrine poroma, there are some studies that have described its dermoscopic findings. These mainly focus on its vascular structures. We present an 82-year-old patient who developed a 2×3-cm eccrine poroma on his lower back. Dermoscopy demonstrated the presence of a polymorphous vascular pattern displaying mostly linear looped (irregular hairpin-like) and “leaf-flower-like” vessels (“cherry-blossom” and “chalice-like”), with some resembling “cactus-like” structures. Only a few linear coiled (glomerular) and linear helical (corkscrew) vessels were observed. Some of these vascular structures were surrounded by a whitish-to-pink halo. Moreover, some pink structureless areas were present. We highlight the finding of the “leaf-flower-like” vessels, as these are vascular structures that have not been described in other types of skin tumors.</p>
Successful Application of Root Cause Analysis on Progressive Cavity Pumps Failures in Orinoco Oil Belt
Authors: Rangel Sara V. , Delgado Algimar S. , Han Micksu J. , Gamez Isaac B. , Rosales Sandra K. , Morety Robert A. , Pereira Jhonatan A. 
Published: September 2016

Abstract
Huyapari Field, located in the Orinoco Oil Belt is operated by PETROPIAR, a joint venture between PDVSA and Chevron, where over 600 horizontal wells have been perforated and completed with progressive cavity pumps (PCP) as the preferred artificial lift method to produce extra heavy oil. With the objective to identify and address the main causes of failure affecting PCPs run life and performance, high repair costs as well as lost production, Root Cause Analysis (RCA) is currently being implemented, giving outstanding benefits by involving both suppliers and customers in a continuous improvement and learning experience.
Between 2003 and 2011, PCP run life was 884 days on average. In 2012, this number decreased dramatically to 306 days with no changes in the reservoir characteristics besides normal depletion. Between 2012 and 2013, 74% of installed PCPs failed before reaching one year in operation, with an average run life of 162 days. Deferred production increased significantly and annual operational expenses duplicated, mostly because of PCP replacements.
In response, Petropiar began in 2013 a joint effort with six manufacturers to review the process involving PCPs selection, design, simulation, transportation, storage, installation, operation, monitoring, diagnostic and pulling. To date, more than 100 pumps have been analyzed applying RCA and including: borescope inspection, destructive analysis, hardness measurement, simulation and review of operating conditions, production history, pump installation & pull out reports, wellbore geometry among others.
The procedure for carrying out this RCA experience and implementing lessons learned is presented in this paper, including identification of various manufacturing quality issues for which, specific tests were put in place to evaluate key characteristics like bonding for example. Quality controls requirements were revisited and elastomers compatibility tests were included as part of the procurement process. On the other hand, new non-conventional technologies have been applied to meet challenging conditions to produce extra heavy oil with high gas production. PCP run life increased by 56% while failures on PCPs with less than 365 days run life decreased by 31% when compared with previous years.
Wettability Alteration During Solvent Assisted-Steam Flooding with Asphaltenes-Insoluble Solvents
Authors: Stape Philip , Hascakir Berna 
Published: September 2016

Abstract
Solvent Assisted-Steam Flooding (SA-SF) was developed to address the environmental and economic challenges associated with steam generation. The solvent composition can greatly affect its interaction with both the asphaltenes present in the oil as well as the clays in the reservoir; therefore solvent selection plays a major role in the process. This study explores the wettability alteration mechanism of oil recovery, and how the solvent selection impacts its performance.
Five experiments were conducted; two chemical flooding (E1 and E2), one steam flooding (E3) and two SA-SF (E4 and E5) experiments. The solvents tested were n-hexane (E1 and E4) and a commercial solvent (CS) (E2 and E5). The wettability alteration caused by the different enhanced oil recovery methods was established through contact angle measurements. The asphaltene and clay content of the produced oil was determined using standard methods. The residual oil content was measured by washing the postmortem samples with toluene, an asphaltene soluble solvent capable of removing all the oil present in the rock. The oil recovery rate was used to measure the performance of each experiment.
Although all experiments had a final wettability that is considered oil-wet, they varied among each other. Experiment E4 showed the least oil-wet surface, while E5 showed the most. At the same time E4 yielded the highest oil recovery of the SA-SF experiments. Lowest clay content and highest asphaltene content was observed in the produced oil of E5, while the opposite was seen in E4. Asphaltene-clay-water interactions in the pores affect the wettability of the rock while the solvent used directly impacts the quantity of asphaltene and clay present. Asphaltenes as insoluble in n-hexane, therefore they precipitate out of the oil onto the rock, interacting with the clay and water to produce a less oil-wet surface, the CS however is composed of heavy dearomatized hydrocarbons which range from C11-C16 and enable more asphaltene production, as all produced oil samples showed.
This study provides a data set for wettability alteration during steam-solvent processes. Our finding suggests that solvents control the wettability alteration due to their interaction with asphaltenes. Wettability varies according to the precipitated asphaltenes polarity and the distance from injection well.
The Research and Application of In-Situ Combustion with Gravity Technology in Thermal Developed Heavy Oil Reservoir
Authors: Wang Lei , Liu Dezhu , Zhang Hongjun , Long Hua , Wu Xiaoming , Hao Ruihui , Liu Jin , Gao Feng 
Published: September 2016

Abstract
Liaohe Oilfield is the largest heavy-oil production base in China, and In-situ combustion with Gravity is one of the emerging new technologies applied in the thermal developed reservoir of Liaohe Oilfield, and this paper mainly introduce four important technologies researched for the development of In-situ combustion with Gravity, including and the ignition technology with the special introduction of the small-diameter removable igniter which could meet the needs of reutilized ignition, the separate air-injection technology with the function of igniting different layers, the horizontal production technology with the integrated tube and the temperature prediction model for horizontal production well, as well as the lifting technology with the high erosion-resistance performance.
In-situ Combustion with Gravity Pilot Test is being conducted in the Shu1-38-32 Block of Liaohe Oilfield, and the Pilot Test shows that all the technologies researched for the In-situ combustion with Gravity have reached the requirements designed in the scheme, especially the ignition temperature monitored in the air-injection well could reach the 527°C, which is the critical condition for the High-temperature Oxidation Combustion. The In-situ Combustion with Gravity shows a great potential to be a nonconventional EOR process, and the experience achieved by the pilot test of In-situ Combustion with Gravity in Liaohe Oilfield will definitely provide references for the development of heavy oil.
How Accurate is Your Well Integrity? A Discussion About the Surface Casing Integrity Under Temperature Loading in Heavy Oil Fields
Authors: Ichim A. C. , Marquez A.. , Teodoriu C.. 
Published: September 2016

Abstract
In various parts of the world, heavy oil projects use high temperatures in order to support the oil production. Most of these projects are still on-going after several years of high temperature well exposure, while others have been suspended due to operational and environmental issues. The well integrity time span should extend itself beyond the field estimated operational date. These wells (observation, productions or abandoned) are highly susceptible to leaks due to cement degradation resulting from thermo-chemical-mechanical loads. Therefore, successful further development of heavy oil reservoirs requires a closer look at the assessment of well integrity and its prediction for extensive periods of time. During the life of the well, the casing-cement-rock system is experiencing, as a secondary problem, a cumulative damage. This could explain the sustained casing pressure that appears after years of good well integrity.
Long time exposure of the well to several loads as well as cyclic load changes may affect the well response due to a rather unexplored degradation of the mechanical, chemical and thermal parameters. In this case, the typical loading mechanisms are thermal, associated with superimposed chemical and mechanical loads. A large number of studies has been conducted to investigate the very complex chemical degradation process of Portland cement systems, which is influenced by temperature, pressure, chemical reactions and their products and, more important, time. A literature review of various investigations on well degradation processes has shown that most of the experiments are time-constrained, and therefore the well integrity is limited to the interval in which results extrapolation is possible. Cement retrogression has also been investigated and research led to recommendations of adding silica flour to the Portland cement. The least investigated aspects of the cements are their cyclic resistance to variable loads.
This paper will critically analyze the various existing well integrity concepts and point out the future need for research to improve the prediction of well integrity. The results of the work show that the major unknowns are long term properties of the downhole environment like casing, cement, and the interaction between casing-cement-formation. Moreover, a simple, yet attention-grabbing experimental investigation has been carried out on several cement samples with different properties by simulating the cement layer associated to the surface casing of a well exposed to temperature variations. Due to the shallow depths, the cementing of the surface casing may yield specific well integrity issues generated by low slurry density requirements, original low temperature environment, high fluid-formation temperature differences, all leading to potential problems related to health, safety and environmental standards worldwide (e.g. aquifers damage, operational risk, etc.).
Viscosity Versus Accuracy – Flow Control Feasibility Workflow in Polymer Flooding
Authors: Gohari Kousha , Jutila Heikki , Kshirsagar Atul , Mascagnini Carlos , Gryaznov Andrey , Askoul Yamal , Harper Christopher 
Published: September 2016

Abstract
The use of horizontal wells for injection and production to help maximise the sweep efficiency and economic recovery; especially for recovery of viscous oil in offshore environments. Flow control devices (FCDs) are readily used to control the flow along the well in conventional recovery operations leading to improved recovery efficiency. The benefits of polymer flooding and FCDs has been well demonstrated, however the combination of the two technologies has yet to be fully realised. The cause of FCDs not being as utilised in polymer injection application is due to the severe degradation of the polymer through devices.
This paper provides a workflow used to determine the benefits of a well planned and executed polymer injection complemented by the optimum flow control strategy. The main focus will be on demonstrating the relative weights in the objective function of optimising the sweep efficiency with the cost of reduced polymer quality. This workflow will allow a number of strategies to be studied, such as the impact of well types, well placement, well lengths, FCDs and polymer viscosities. The impact of polymer viscosity reduction in an injector well with FCDs is of particular interest. Hence the trade-off of the polymer degradation and the ability to get the required polymer quantity in the various segments of the well will be described.
The feasibility of polymer flooding with flow control is a viable alternative for classical enhanced oil recovery (EOR) but the decision whether or not to implement it has to be based on prudent analysis and decision making process. Hence the study highlights the importance of understanding uncertainties with control as well as those associated with reservoir and geology.
Flow Visualization for Performance Measurement across Sand Control Orifices
Authors: Rasimarzabadi Faezeh , Leitch Michael , Ansari Shadi , Nobes David S. 
Published: September 2016

Abstract
The flow of fluids through sand control apertures, such as slots in slotted liners, is critical to the performance of heavy oil wells using Steam Assisted Gravity Drainage (SAGD) or other enhanced methods. Advanced optical image techniques were used to measure the in-situ flow velocity and pressure difference along slots of varying cross sectional profiles. The experimental slot was made as a two-dimensional channel in acrylic sheet to allow excellent visualization. The slots were full scale and varying in geometry: straight slots, keystone slots, and wire wrap screens were evaluated. Measurements were made for a Newtonian fluid (water) at different flow rates over the ranges expected in the field. Captured velocity profiles and non-dimensional pressure were compared with analytical theory. The corss-sectional profile of the slot affects flow characteristics which in turn affect the pressure difference developed across the sand control screen.
Quantification of the Distribution of Initial Water Saturation through Leverett J Function to Calculate Hydrocarbon Reserves
Authors: Gonzalez J. W. , Perozo A. E. , Medina F. X. 
Published: September 2016

Abstract
Generally, hydrocarbon reserves are determined by the irreducible water saturation using the volumetric equation of the original oil in place (OOIP), regardless of the initial water saturation in the transition zone and as a result overestimate hydrocarbon reserves. The objective of this work is to determine a water saturation model that allows modeling the initial distribution of fluids in the reservoir knowing the original oil-water contact and rock quality.
The Leverett J function was used as a variable independent from initial water saturation model; it controls the flow of fluid and depends on the height above the free water level, the interfacial tension, Oil-water fluid density, absolute permeability and effective porosity. In order to define this function, capillary pressure data from oil-water system of drain cycle from special core analysis were used. The core data were modeled and averaged for each rock type with the capillary pressure function from "JNM Jing XD Van Wunnik SCA-9807 (1998)". Then, these curves were converted to values of "J" and these were related with water saturation from capillary pressure curves to obtain functions type SWINIT: f (J).
This model gave excellent results in the fluid initial behavior, it means, knowing the original oil-water contact and rock quality, the initial water saturation was quantified in in wells completed in the reservoir. The aforementioned was validated with production / pressure tests. Finally, two sensitivities were performed to calculate OOIP, the first was determined with the irreducible water saturation and the second with the initial water saturation, resulting in a error difference about 5%, in this case, obtaining higher reserves were the calculated with irreducible water saturation.
The initial water saturation profile of the wells generated from the model, it is useful to initialize the numerical simulation from reservoir "A", because this model takes as an input data the original oil water contact, which represents the limit reservoir fluid. This model does not depend on the date of drilling wells to determine the initial water saturation of the reservoir.
Integrated Methods for Identifying Opportunities to Efficiently Develop Heavy Oil in the Block 192 - Peru
Authors: Zafra W.. , Erazo A.. , Soriano Arambulo V. H. , Wu X.. 
Published: September 2016

Abstract
Heavy oil production presents tremendous challenges in subsurface development, production wells, and surface transport. Therefore, highly efficient transportation calls for innovative engineering processes to facilitate the transport from subsurface to downstream. In Block 192- Peru, previous production experience indicated that mixing light oil at the well production manifold to heavy oil stream was a feasible option. However, this option strongly depends on the availability of light oil. The aim of this study is to present alternatives to improve heavy oil transportation performance in the block 192.
Results of a fundamental study conducted on the heavy oil transportation performance in Jibaro, Jibarito and San Jacinto fields are presented herein where multiple possibilities are evaluated to reduce the ratio of light oil per barrel of heavy oil production (i.e. to increase the efficiency of the diluent). This study provides guidelines to select one of the three following methods: diluent injection, emulsion injection or reservoir-based technology. Previous operators performed extensive reservoir characterization and simulation modeling which led to recovering over 200 million barrels of heavy oil (up to July 2015) through Vivian sands. Therefore, this confirmed the suitability of introducing new methods to feasible transport and sell heavy oil.
Jibaro, Jibarito and San Jacinto fields are used in this study due to their significant heavy oil reserves. The complexity of these fields includes high water cut production, Heli transportable logistics and high cost of produced oil. The first method proposed in this study consists of injecting a diluent in the extraction stream of heavy oil up. The second method uses emulsion water to transport high viscous oil. The third method involves applying a technology in the extraction process to reduce the viscosity of heavy oil, and in-situ upgrade the heavy oil up to sales specifications with a consideration of long distance between fields. This study concludes that a conceptual engineering and a selection of a compatible diluent and solvent are critical. Finally, environmental permitting increases the complexity of any project in the area and the possibility to introduce new technology.
Influence and Determination of Mechanical Skin in a Reservoir with a Fractal Behavior
Authors: Posadas-Mondragón R.. , Camacho-Velázquez R.. 
Published: September 2016

Abstract
This paper reviews some concepts related to the evaluation of the wellbore pressure behavior in a fractal reservoir. The purpose of this work is to show the impact of the mechanical skin on the pressure drop and its derivative behavior, and therefore on the interpretation of the well test data to determine parameters of a reservoir with fractal geometry.
We use the solution for an infinite fractal reservoir without and with matrix participation, with a well producing at constant rate, including wellbore storage and skin effects. This solution is in the Laplace domain; applying numerical inversion with the Stehfest algorithm we obtain the pressure solution in time.
It is shown that the characteristic power law behavior of both pressure drop and semilogarithmic derivative not only depends on the parameters of fractal dimension (dmf) and connectivity index of fractures (θ), but also on the skin factor. The parallel straight lines behavior may be valid at long times during the transient period, but at early times, the skin and wellbore storage effects may inhibit this behavior. This effect, at early times, is greater for fractal dimension values close to the Euclidian dimension (i.e. dmf~2).
Thus, if the fractal dimension (dmf) and/or the connectivity of fractures decrease (θvalue increases), the pressure drop in the reservoir may be larger than the pressure drop due to the skin effect, consequently the parallel behavior of pressure and its derivative would be even valid at early times. But if the skin is big enough, the parallel behavior would only be valid at long times during the transient period.
The direct determination of the skin is not possible for these systems because the skin and fractal parameters are affecting the pressure response at the same time. A new definition of dimensionless time, which includes a new equivalent wellbore radius concept to take into account the skin effect in a general way, is proposed. With this definition of dimensioless time, it is possible to get the parallel straight lines behavior even at early times.
It is presented a sensibility analysis to fractal dimension, connectivity of the fracture network, skin factor and wellbore storage constant, for a well on a radial fractal reservoir.
The proposed methodology is important because the direct determination of the skin is not possible for fractal systems as it can be done for classical Euclidean reservoirs, with a logarithmic behavior, mainly because the skin and fractal parameters are affecting the pressure response at the same time.