bluuebunny/crossref_metadata_2025_split huggingface dataset:
Proppant Crush Test: A New Approach
Authors: Simo Herve , Pournik Maysam , Sondergeld Carl. H. 
Published: March 2013

Abstract
Hydraulic fracturing is the most efficient stimulation technique used to enhance productivity in low permeability reservoirs with the productivity enhancement strongly dependent on the resulting conductivity. In order to maintain conductivity under increasing load, proppant must be able to withstand the closure stress at the concentration level that it is present in the fracture. Among the most important characteristics for proppant selection are strength and bulk density.
Current standard procedure for measurement of proppant strength is based on concentration of 4 lb/ft2 and determination of percent crushed proppant under a specified load. The procedure does not represent realistic field conditions and fails to capture the effect of increasing closure stress on proppant and fracture conductivity loss. In this paper, a new technique to determine the failure stress of proppant is proposed and a summary of the results are presented. This new approach enables us to not only determine the behavior of different proppant pack over a wide range of pressures but also to determine failure point of proppant at a given concentration.
The new proppant crush test approach was used to compare the strength of 40/70 sand, 40/70 resin coated sand, 30/50 sand, and 30/50 resin-coated sand. The failure stresses for the above proppants were determined as a function of proppant concentration. A significant increase in failure stress was observed as proppant concentration varied from 0.5 to 2 lb/ft2. Failure stress was relatively constant for proppant concentration greater than 2 lb/ft2. In addition, different pattern of proppant behabior with closure stresse was observed for resin coated sand at concentrations above 2 lb/ft2 as compared to all other proppants and other concentrations.
Evaluation of Near-Wellbore Formation Treatment by Gel Particles Using Dimensional Analysis
Authors: Al-Ibad Adnan , Civan Faruk 
Published: March 2013

Abstract
Analysis and interpretation of experimental data of laboratory tests of porous formation treatment by gel particles conducted at different gel particles suspension and application conditions are presented based on the dimensional analysis method. The measured permeability reduction caused by gel particles suspension injection into sand packs is correlated successfully by using the dimensionless groups developed from the relevant variables of sand packs, gel particles suspensions, and application operation conditions. The dimensionless correlations are shown to assist in quantifying the effect of the particle-diameter to pore-throat size ratio on permeability reduction, evaluating the treatment of highly permeable and weak near well-bore formations by gel particles, and extrapolating from laboratory to field conditions. The present dimensionless correlations can predict the evolving permeability reduction under the varying conditions of gel particles suspension injection processes. The proposed dimensionless correlations can assist in effective design and mitigation of treatment of high-permeability near-wellbore formations by gel particles for avoiding drilling-fluids lost circulation, remediating reservoir permeability heterogeneity, and reducing water production in waterflooded mature oil fields.
Successful Application of Innovative Reaming and Completion Technology in Williston Basin Wells
Authors: Scott G. , Smith L. M. 
Published: March 2013

Abstract
In multiple wells in the Williston Basin of North Dakota, introduction of a new reaming tool utilized for dedicated reaming and reaming-while-drilling operations has been introduced successfully in over 140 wells.
This new tool has increased the percentage of packers going to total depth (TD) in a single trip in Williston Basin wells, where it is critical that wellbore condition enables multiple packers to be run and set at TD in a timely fashion in a single trip.
Additionally enhanced packer design, in combination with a better understanding of well bore conditions as well as improved torque and drag reductions, has led to additional field successes. Historically this has not been the case in a number of wells, and information will be provided on certain of those instances.
The reaming tools are currently bring used in reaming-while-drilling scenarios to eliminate the need for a dedicated reamer run in each well; this saves two to three rig days.
These tools can be built as steel or non-magnetic (non-mag) tools; hence, they can be run anywhere in the BHA plus be used to drill out. They reduce spiraling in the well bore, thereby reducing the risk of sticking the liner assembly before reaching TD.
Operators are 100% successful with packers going to TD when using this technology. In addition, current BHA modeling techniques and field use documents that use of the tools presents no significant steerability issues and no loss in penetration rate while still enabling subsequent installation of multiple packers. This proved critical in these North Dakota wells, where the application can require running as many as 35 swell packers to bottom.
Also provided is input on certain packer designs that can be used in combination with these new reaming technologies to improve the chances for going to TD in a single run.
Finally, the paper addresses the economic impact of this reamer application in what can be a half-million dollar operation per well, and notes the on-going progress of reaming-while-drilling efforts to date.
Optimization of Multiple Hydraulically Fractured Horizontal Wells in Unconventional Gas Reservoirs
Authors: Yu Wei , Sepehrnoori Kamy 
Published: March 2013

Abstract
Accurate placement of multiple horizontal wells drilled from the same well pad plays a critical role in the successful economical production from unconventional gas reservoirs. However, there are high cost and uncertainty due to many inestimable and uncertain parameters such as reservoir permeability, porosity, fracture spacing, fracture half-length, fracture conductivity, gas desorption, and existing natural fractures. It is absolutely important to investigate reasonable ranges for these uncertain parameters and evaluate their effects on well performance for the purpose of improving stimulation designs and completion strategies. In this paper, we employ Response Surface Methodology (RSM) to optimize multiple horizontal well placement to maximize Net Present Value (NPV) with numerically modeling multistage hydraulic fractures in combination with economic analysis.
This paper demonstrates the accuracy of numerical modeling of multistage hydraulic fractures for actual Barnett Shale production data by considering the gas desorption effect. Six uncertain parameters, such as permeability, porosity, fracture spacing, fracture half-length, fracture conductivity, and distance between two neighboring wells with a reasonable range based on Barnett Shale information, are used to fit a response surface of NPV as the objective function, and to finally identify the optimum design under conditions of different gas prices based on NPV maximization.
This integrated approach can contribute to obtaining the optimal drainage area around the wells by optimizing well placement and hydraulic fracturing treatment design and provide insight into hydraulic fracture interference between single well and neighboring wells. Also, it can be used to decide whether or not fracture design needs to be adjusted for closer well placement and provide guidance for engineers to modify the design of a hydraulic fracture treatment prior to the actual fracture treatment and to determine the optimal number of horizontal wells for a specified area.
Field and Lab Experience with a Successful Preformed Particle Gel Conformance Control Technology
Authors: Bai Baojun , Wei Mingzhen , Liu Yuzhang 
Published: March 2013

Abstract
Gel treatment is a cost-effective method for oilfield conformance control. Traditionally, in-situ gels formed by the reaction of polymer and crosslinker at reservoirs have been used widely to control conformance. However, a newer trend is to apply preformed particle gels (PPGs) for this purpose because they are formed at surface facilities before injection and they overcome some distinct drawbacks inherent in in-situ gelation systems, such as lack of control over the gelation time, gelling uncertainty due to shear degradation, chromatographic fractionation or change of gelant compositions, and dilution by formation water. PPGs are characterized as having robust gel chemistries and as being highly insensitive to petroleum reservoir environments and interferences. They can resist temperatures up to 120 °C (250 °F) and are compatible with any kind of formation water. In this paper, we describe and discuss our extensive laboratory and field experiences with the widely applied and successful PPG technology. Highlights of illustrative PPG field applications and results are presented. An overview of what over a decade of experience in applying the PPG technology has taught us is discussed. This includes a discussion of classifying and distinguishing conformance problems and treatments, attributes of good candidate wells, requirements that must be met in candidate wells, gel treatment elements that must be implemented successfully to achieve success, and the guidelines as to where PPG conformance treatments are applied most successfully.
Formation Damage Caused by Pipe Dope and Its Remediation
Authors: Mathis Julie , Goretta Emiliano Actis , Saubidet Martin Lopez , Castiñeiras Tomas , Funes Alejandro , Figini Fernando , Wang Xiuli , Economides Michael J. 
Published: March 2013

Abstract
Historically all well strings of casing and tubing have used thread compound or “dope” to enable good connectivity, lubricity and sealability of connections. During the makeup of a connection, excess running compound or dope is squeezed out into the annular space where it can gain access to wellbore fluids and cause formation damage. The innovation of surface technologies and industrial coatings allowed the development of dope-free connections. Dope-free technology can potentially eliminate the use of all dopes in well construction.
Formation damage caused by excess pipe dope is not a recently developed problem but has been overlooked in the past. This, perhaps, is because the problem for production applies to higher formation permeability than the ones studied in this paper. For relatively low-permeability formations whose pore throats are smaller compared to dope particles and therefore the latter do not penetrate the rock matrix, the problem can be mitigated by the flow of reservoir fluids The problem can also be diminished by using solvent treatments (such as toluene or xylene) to help break down and dissolve the dope compounds.
The key benefit of dope-free technology is the prevention of damage to the formation caused by dope entering the formation. Additional benefits include a more reliable and robust connection and a more efficient well site assembly process. Dope-free technology guarantees better downhole performance, minimization of galling and other connection damage as well as immediate savings in the operation by removing a routine and uncontrolled manual operation on the rig floor. Reduction of heavy tubular handling and lifting operations as well as the achievement of a virtual no discharge of effluents are also important benefits.
In this paper, we present the laboratory test results utilizing actual core samples. Results show the creation of a harmful dope suspension that can penetrate and damage the formation. During injection operations this can result in severe damage to the well formation (greater than 99%), while in production operations the damage depends on the reservoir permeability. Within the tested permeability range (&lt;288 md), it is observed that the harmful compounds did not penetrate the rock matrix and, instead, it formed a filter cake that can be removed by reservoir fluid flow while in injection mode.
This paper will demonstrate the benefits of using dope-free pipe connections by quantifying the negative effects of the traditional way of joining connections with dope. Various “thread dopes” are tested, showing the differing potential damage from the dope product used. Production equations using a dope-induced skin effect are also presented, showing the detrimental impact on well performance.
An Experimental Study on Liquid Loading of Vertical and Deviated Gas Wells
Authors: Yuan G. , Pereyra E. , Sarica C. , Sutton Robert P. 
Published: March 2013

Abstract
The main objectives of this experimental study are to explore mechanisms controlling the onset of liquid loading and to investigate effect of well deviation on liquid loading. An experimental study of liquid loading of gas wells has been conducted with air/water flow in a 3-inch pipe at well deviations of 0°, 15° and 30° from vertical. A total of 131 tests have been carried out. Differential pressure gradient and liquid holdup were measured. Flow pattern was observed and videos were captured with a high speed video system. Critical gas velocity which defines the threshold for liquid accumulation in a well (commonly termed liquid loading) has been identified by analyzing different measurements including video captures. Results show different mechanisms for vertical and inclined pipe flows. A minimum pressure gradient criterion can be applied to determine the critical gas velocity. Well deviation angle has an effect on critical gas velocity. Performance analysis for various models has revealed their shortcomings.
3-D Simulation of Carbonate Acidization with HCl: Comparison with Experiments
Authors: Maheshwari P. , Balakotaiah V. 
Published: March 2013

Abstract
Acidization of carbonate rocks is a common practice to reduce the formation damage near wellbore. In this process, an acidic solution is injected to dissolve some of the rock that creates conducting channels called wormholes. These wormholes facilitate the flow of hydrocarbons to the wellbore. In the literature, there are several theoretical and experimental studies performed to understand this process. However, there are very few 3-D numerical studies that can predict quantitatively the experimental results such as the optimum injection rate. An accurate prediction of the optimum acid injection rate is necessary for field scale operations. Therefore, the main objective of this study is to quantitatively predict the experimentally observed acidization curve (amount of acid required to breakthrough versus acid injection rate), so that the validated model could be used for field scale simulations.
In this study, we present 3-D simulation of carbonate acidization with HCl using a two-scale continuum (TSC) model. The model describes the reactive transport at Darcy scale and retains all pore scale physics through structure-property relations. Unlike previous studies, we use a new two-parameter (pore-broadening and pore-connectivity) structure-property relation to describe the change in permeability, pore radius and interfacial area per unit volume with porosity. We predict quantitatively the experimentally observed acidization curve for HCl-limestone system and show the existence of a critical heterogeneity (that corresponds to minimum amount of acid required to breakthrough). We also present scaling criteria to estimate the wormhole tip diameter and optimum acid injection rate, for vuggy and non-vuggy carbonates. Finally, we present the flow dynamics of acid inside the wormhole.
Production and Injection Monitoring and Surveillance
Authors: Agudelo O. , Amaya M. , Nunez G. , Volante M. , Escalona C. 
Published: March 2013

Abstract
The Casabe Technology Alliance between Ecopetrol and Schlumberger started its operation in 2004 in Casabe field. The field came originally into production several decades ago and by 2004 was producing close to 5,000 BOPD.
The alliance has since redevelopment the field with an aggressive strategy to increase Oil production through selective water injection for secondary recovery. The redevelopment considered a significant increase of production and selective injector wells, something that poses a challenge in terms of injection and production data handling, engineering worklfows for better decision making.
During the time Casabe Project began complicate by the workover, drilling and waterflooding activities that are performing for the alliance beside the complicate mature reservoir condition and the original date base, that was un integrated, with duplicity data, without control quality, storage limit, etc. Where at the end of the days the engineers were spending more than 80% of time, searching date and 20% of time integrating and analyzing information to solve field problem and make decision.
For that reason Casabe alliance decide creation a project that helps integrate different components to reduced engineer time to analysis field data and make appropriate and quickly decision.
This project key implementation stages included:
Component 1: Data Management ■ Data consolidation and creation of one unique data source of information for Casabe's asset historical production. Component 2: Production business processes and mapping of information flows. ■ Analyze and document the current injection / production process, to identify improvements related to data management Component 3: Production information and engineering workflows management ■ Integrate System→ Identify workflows based on reservoir surveillance. ■ Data visualization and alarms generation. ■ Link operational database with the other applications, like as: Reservoir Monitoring and Analysis. ■ Ensure data quality for the follow up and analysis.
Application of Mass Balance and Transient Flow Modeling for Leak Detection in Liquid Pipelines
Authors: Rivas Karent V , Civan Faruk 
Published: March 2013

Abstract
Effective methodologies implementing proper flow hydraulics simulation approaches are presented for accurate leak detection in natural gas liquid (NGL) pipelines under steady- and transient-state flow conditions based on mass and force balance principles and head and flow measurements taken at pipeline end-points. Leak detection curves are generated using a process simulation package under steady-state operation conditions for systems with prescribed fluid compositions, pipeline characteristics, and instrumentation accuracy. Real-time transient-state leak detection along a pipeline is accomplished by simulation of pipeline fluid conditions with a proper flow model. Typical transient-state flow episodes are demonstrated for pump-start up and valve closing cases. Real pipeline data are facilitated in the leak detection model by implementing a time-marching algorithm. Deviations of patterns for measured inlet and outlet flow conditions and heads are facilitated for detection of occurrence and locations of leaks. It is shown that the response time depends on the leak location and has the lowest value for leaks occurring near the pipeline middle-point, leak location can be predicted based on the time required for detection of a discrepancy, and estimation of leak location is more difficult when the mass of pipeline fluid and hence resistance to flow increase. Proposed approaches can be instrumental for critical review and assessment of the physical characteristics, limitations, capabilities, and instrumentation adequacy of pipelines for safe operation and proper selection of effective leak detection technologies and instrumentation upgrades with improved response time and accuracy required for pinpointing of leak locations and estimation of leak sizes.
Intravenous Gammaglobulin Inhibits Encephalitogenic Potential of Pathogenic T Cells and Interferes with their Trafficking to the Central Nervous System, Implicating Sphingosine-1 Phosphate Receptor 1–Mammalian Target of Rapamycin Axis
Authors: Othy Shivashankar , Hegde Pushpa , Topçu Selma , Sharma Meenu , Maddur Mohan S. , Lacroix-Desmazes Sebastien , Bayry Jagadeesh , Kaveri Srini V. 
Published: March 2013

Abstract
Despite an increasing use of high-dose therapy of i.v. gammaglobulin (IVIg) in the treatment of various T cell– and Ab-mediated inflammatory and autoimmune diseases, comprehension of the mechanisms underlying its therapeutic benefit has remained a major challenge. Particularly, the effect of IVIg in T cell–mediated autoimmune conditions remains unexplored. Using an actively induced experimental autoimmune encephalomyelitis model, a T cell–mediated autoimmune condition, we demonstrate that IVIg inhibits the differentiation of naive CD4 T cells into encephalitogenic subsets (Th1 and Th17 cells) and concomitantly induces an expansion of Foxp3+ regulatory T cells. Further, IVIg renders effector T cells less pathogenic by decreasing the expression of encephalitogenic molecular players like GM-CSF and podoplanin. Intriguingly and contrary to the current arguments, the inhibitory FcγRIIB is dispensable for IVIg-mediated reciprocal modulation of effector and regulatory CD4 subsets. Additionally, F(ab′)2 fragments also retained this function of IVIg. IVIg or F(ab′)2 fragments decrease the sphingosine-1 phosphate receptor on CD4 cells, thus sequestering these cells in the draining lymph nodes and decreasing their infiltration into the CNS. Our study reveals a novel role of Igs in the modulation of polarization and trafficking of T lymphocytes, accounting for the observed beneficial effect in IVIg therapy.
Inflammatory Response of Mast Cells during Influenza A Virus Infection Is Mediated by Active Infection and RIG-I Signaling
Authors: Graham Amy C. , Hilmer Kimberly M. , Zickovich Julianne M. , Obar Joshua J. 
Published: March 2013

Abstract
Influenza A virus (IAV) is a major respiratory pathogen of both humans and animals. The lung is protected from pathogens by alveolar epithelial cells, tissue-resident alveolar macrophages, dendritic cells, and mast cells. The role of alveolar epithelial cells, endothelial cells, and alveolar macrophages during IAV infection has been studied previously. In this study, we address the role of mast cells during IAV infection. Respiratory infection with A/WSN/33 causes significant disease and immunopathology in C57BL/6 mice but not in B6.Cg-KitW-sh mice, which lack mast cells. During in vitro coculture, A/WSN/33 caused mast cells to release histamine, secrete cytokines and chemokines, and produce leukotrienes. Moreover, when mast cells were infected with IAV, the virus did not replicate within mast cells. Importantly, human H1N1, H3N2, and influenza B virus isolates also could activate mast cells in vitro. Mast cell production of cytokines and chemokines occurs in a RIG-I/MAVS–dependent mechanism; in contrast, histamine production occurred through a RIG-I/MAVS–independent mechanism. Our data highlight that, following IAV infection, the response of mast cells is controlled by multiple receptors. In conclusion, we identified a unique inflammatory cascade activated during IAV infection that could potentially be targeted to limit morbidity following IAV infection.