bluuebunny/crossref_metadata_2025_split huggingface dataset:
Solid surface free energy analysis using inkjet droplets
Authors: Fukada Kazuhiro , Sakai Hayato , Hasobe Taku , Masuda Takashi , Shimoda Tatsuya 
Published: March 2012

ABSTRACTWe measured the surface free energy of a substrate by transmission electron microscopy (TEM) using sub-millimetre-sized inkjet droplets. By employing two types of TEM grids with different surface free energies, we investigated the relationship between the surface energy and the patterns of an organic solution dried on the grids. We confirmed that the generation of the porphyrin hexamer [(H2PAC15)6TPh] patterns was affected by the surface free energy of the TEM grid.
Sophisticated Software Analysis System and Use of Torque/Drag Modeling for Complex Well Operations Increases Operational Efficiency
Authors: Xie Liangjun , Moran David , Yan Lei , Mercado Jose , Mercado Jose 
Published: March 2012

Abstract
Accurate torque and drag (T&D) analysis is a fundamental well planning tool essential for predicting and preventing drilling and completion problems. To guarantee an efficient and safe operation, tension/compression and torque on the bottom hole assembly needs to be controlled within acceptable limits. Practically all available torque and drag software can calculate the following general operation modes: rotating off-bottom, pick-up, slack-off, rotary drilling and oriented drilling modes.
However in the well construction process, there are many other complex operational modes that are largely absent from available software systems, as discussed in the literature. The industry requires modeling methodology to analyze complex well operations including: setting and un-setting packers, anchoring liner hangers, shearing pins in wellbore departure operations, loading and operating drilling/fishing jars in both overpull and compression.
The authors will discuss new modeling software capable of analyzing complex well operations including liner hanger and jarring operations in detail. Further discourse about how modeling these special operations were combined with field experience and confirmed the accuracy of the new module with regards to both special operations and conventional T&D capabilities. The simulation/analysis recommendations were successfully executed in the field and led to increased operational efficiency and unplanned cost avoidance. Case studies will be presented of successful liner hanger deployment and complex drilling jar simulation.
Semiautomatic, Semantic Assistance to Manual Curation of Data in Smart Oil Fields
Authors: Chelmis Charalampos , Zhao Jing , Sorathia Vikram , Agarwal Suchindra , Prasanna Viktor 
Published: March 2012

Abstract
Vast volumes of data are continuously generated in smart oilfields from swarms of sensors. On one hand, increasing amounts of such data are stored in large data repositories and accessed over high-speed networks; On the other hand, captured data is further processed by different users in various analysis, prediction and domain-specific procedures that result in even larger volumes of derived datasets.
The decision making process in smart oilfields relies on accurate historical, real-time or predicted datasets. However, the difficulty in searching for the right data mainly lies in the fact that data is stored in large repositories carrying no metadata to describe them. The origin or context in which the data was generated cannot be traced back, thus any meaning associated with the data is lost. Integrated views of data are required to make important decisions efficiently and effectively, but are difficult to produce; since data is being generated and stored in the repository may have different formats and schemata pertaining to different vendor products.
In this paper, we present an approach based on Semantic Web Technologies that enables automatic annotation of input data with missing metadata, with terms from a domain ontology, which constantly evolves supervised by domain experts. We provide an intuitive user interface for annotation of datasets originating from the seismic image processing workflow. Our datasets contain models and different versions of images obtained from such models, generated as part of the oil exploration process in the oil industry. Our system is capable of annotating models and images with missing metadata, preparing them for integration by mapping such annotations. Our technique is abstract and may be used to annotate any datasets with missing metadata, derived from original datasets.
The broader significance of this work is in the context of knowledge capturing, preservation and management for smart oilfields. Specifically our work focuses on extracting domain knowledge into collaboratively curated ontologies and using this information to assist domain experts in seamless data integration.
Test of SAGD Flow Distribution Control Liner System, Surmont Field, Alberta, Canada
Authors: Stalder John L. 
Published: March 2012

Abstract
Surmont well pair 102-06 started SAGD operation in April 2009 with flow distribution control built into the horizontal liners for both the injection well and the production well. After preheat steam circulation, this liner system has allowed operation without a toe tubing string in either completion and has delivered superior steam chamber development and overall performance. The design also allowed reducing the liner and casing size for the injection well. Future SAGD well design may benefit by further reduction in liner and casing sizes for both the injector and producer which could allow longer completions by reducing liner drag and increasing directional drilling flexibility. Ultimately these SAGD well design changes could increase the amount of reservoir developed per well and per well pad using longer wells and more wells per pad while achieving superior SAGD performance.
Simulation and Economic Screening of Improved Oil Recovery Methods with Emphasis on Injection Profile Control Including Waterflooding, Polymer Flooding and a Thermally Activated Deep Diverting Gel
Authors: Okeke Tobenna , Lane Robert 
Published: March 2012

Abstract
The large volumes of water produced during oil extraction presents a significant problem due to the high cost of handling and disposal in an environmentally friendly manner. On average, an estimated seven barrels of water is produced per barrel of oil in the US, and the associated treatment and disposal cost is an estimated $5-10 billion annually.
Water production can be particularly problematic during waterflooding in highly heterogeneous reservoirs with vertical communication between layers leading to unevenness in the flood front, cross-flow between high and low permeability layers and early water breakthrough from high permeability layers. Some of the different technologies that can be used to counteract this involve reducing the mobility of water or using a permeability block in the higher permeability, swept zones. Selective permeability blockage, however, is particularly difficult where crossflow is possible.
This research was initiated to evaluate the potential effectiveness of an approach to the latter method, known as deep diverting gels (DDG) to plug thief zones deep within the reservoir and far from the injection well. To evaluate the performance of DDG, its injection and placement was modeled, sensitivities run for a range of reservoir characteristics and conditions and a rudimentary economic analysis was performed. Performance of the DDG is compared to waterflooding and polymer flooding from a technical and economic perspective.
A literature review was performed on the background of injection profile control methods, their respective designs and technical capabilities. Commercial software was used to simulate the behavior of these methods in a reservoir using simplified assumptions of reservoir characteristics and fluid properties. Simulation results were used to carry out economic analyses of the recovery methods. Results show that the largest impact on economics was incremental oil produced. Polymer flooding had the highest NPV in all case comparisons followed by DDG.
The Study of Timing of Cyclic Injections in Miscible CO2 WAG
Authors: Jiang Haifeng , Nuryaningsih Lily , Adidharma Hertanto 
Published: March 2012

Abstract
When water alternating gas flooding utilizing carbon dioxide (CO2 WAG) is injected at different stages after secondary recovery, the difference in oil/water/gas saturations influences the micro and macro displacement efficiencies due to multiple mechanisms, thus the performance of WAG could be different and an optimum timing could exist. In this study, the timing of cyclic injections in miscible CO2 WAG is experimentally investigated.
WAG performance is studied in core flood experiments performed in Berea sandstone cores. Synthetic brines and South Slattery crude oil from Wyoming are used to restore the core to its reservoir conditions, and ultra high purity CO2 is used as the miscible gas. The experiments are conducted at 57°C and at a pressure 20% above the minimum miscibility pressure (MMP) to ensure miscible condition; slim tube experiments to obtain the MMP of the system are performed prior to the core floods. The experiments utilize a WAG ratio of 1:1, an optimized half cycle slug size of 0.1 PV, and a total slug size of 2 PV. The timing of cyclic injections is studied by introducing WAG at different stages between secondary and tertiary mode. The WAG performance is determined by analyzing the percent oil recovery, CO2 breakthrough time, and tertiary recovery factor (TRF)
The earlier WAG is injected, the longer CO2 stays in the core before its breakthrough. However, the results show that the best timing of cyclic injections for miscible CO2 WAG is when water flooding produces half of the oil that can be flooded by secondary recovery alone, i.e., when the flood front passes through the middle of the core. Injecting WAG too early or too late will result in either low macro sweep efficiency or low micro displacement efficiency. The analysis also shows that the phenomena are the results of multiple mechanisms.
Similar studies using numerical simulations have been reported but never been experimentally investigated. The study of timing of cyclic injections is essential in understanding the mechanisms, as well as optimizing the performance of miscible CO2 WAG.
Determination of Water Injection Zonal Allocation From Distributed Temperature Sensing Data
Authors: Mehtiyev Nijat , Rahman Mahmood , Bourgoyne Dwayne 
Published: March 2012

Abstract
Operators including Aera Energy LLC are evaluating distributed temperature sensing (DTS) systems as an alternative to production logging tools (PLT) and radioactive tracer surveys (RTS) for the determination of zonal allocation factors. If DTS data can be interpreted to provide wellbore velocities, zonal allocation can be determined without well entry and practically in real-time. In comparison to PLT and RTS, DTS could provide zonal allocation at a higher measurement frequency, lower cost, and lower risk to personnel, environment, and the well asset. In wells where casing deformation precludes wireline operations, DTS may be the only viable alternative. The purpose of this work is to investigate whether water injection zonal allocation can be derived from DTS data acquired in thermal tracer injection tests within an uncertainty comparable to RTS. Three waterflood injection wells with RTS and DTS data in Aera Energy"s Belridge field in California are analyzed. The zonal allocation factors derived from the DTS are shown to agree within uncertainty with the RTS-based results. The DTS for two of the wells is interpreted through history matching with an OLGA thermal-fluid model. The DTS for a third well is interpreted using the Temperature Inflection Point (TIP) thermal tracer method proposed in this work. The TIP method is a simpler alternative to history matching and was shown to be theoretically valid for wells with negligible heat transfer at the walls over the duration of the injection test. In this regard the TIP method is less restrictive than the Slopes method, which is currently used in industry but theoretically requires negligible heat transfer at the walls and within the fluid. The TIP method is also shown to be more consistent with the field data of this study. The paper concludes with guidelines on the design and implementation of thermal injection tests and TIP analysis. The most significant practical limitation of the TIP method is its sensitivity to noise in the data, motivating DTS acquisition at the maximum practical resolution, data smoothing, and averaging over multiple test realizations.
Natural Proppants for Hydraulic Fracture Production Optimization in Eagle Ford Shale
Authors: Yang Mei , Economides Michael J. 
Published: March 2012

Abstract
Proppants are essential to the success of most hydraulic fractures and often account for a significant portion of the cost of the treatment. Both the mass of proppant and the selection of the right type of proppant are critical elements in gaining the highest Net Present Value (NPV).
It has been generally believed that in a lower closure stress environment (below 6,000 psi, i.e., shallow reservoirs), natural sands such as Brady and Ottawa types are appropriate as proppants and, for the same mesh size, they provide essentially the same permeability. Commonly accepted notion is that manmade proppants (such as ceramics) should be applied at higher closure stress environment, invariably deeper reservoirs.
According to the characteristics of Eagle Ford shale, which include the rock stiffness, exemplified by Young&apos;s Modulus, stress anisotropy or isotropy and the existence of a natural fracture network, this study presents fracture designs based on three types of proppants for both shale formations: Brady sand, Ottawa sand and man-made ceramic. Permeability tests and crush tests under certain pressure ranges are done to determine experimentally the dimensioned fracture conductivity. Although natural proppants may exhibit lower permeability, a fracture optimization p-3D model is used to remedy the lower proppant permeability and maximize well performance by optimizing fracture geometry, including fracture half length, width and height. Reduced proppant pack permeability is compensated by larger width. Non-Darcy effects in the fracture are also considered for gas reservoirs. Post-treatment well performance is then estimated, using the optimized well geometry, leading to cumulative production estimates over the well life. Finally, a NPV analysis is employed as the criterion to select the best proppant for the job.
In this study, we show there is an optimum Proppant Number corresponding to maximum NPV for various reservoir permeabilities. Based on that notion, we propose a systematic way of choosing proppant type and mass to maximize NPV in oil reservoirs. For tight gas reservoirs, we correct the prejudice that natural sand proppants cannot be applied to deeper reservoirs by showing NPV study results that are superior to those of manmade proppants. By keeping stimulation costs down, natural sand proppants have a much larger range of applicability than previously thought.
Grid-Based Surrogate Reservoir Modeling (SRM) for Fast Track Analysis of Numerical Reservoir Simulation Models at the Grid block Level
Authors: Mohaghegh Shahab D. , Amini Shohreh , Gholami Vida , Gaskari Razi , Bromhal Grant 
Published: March 2012

Abstract
Developing proxy models has a long history in our industry. Proxy models provide fast approximated solutions that substitute large numerical simulation models. They serve specific useful purposes such as assisted history matching and production/injection optimization. Most common proxy models are either reduced models or response surfaces. While the former accomplishes the run-time speed by grossly approximating the problem the latter accomplishes it by grossly approximating the solution space. Nevertheless, they are routinely developed and used in order to generate fast solutions to changes in the input space. Regardless of the type of model simplifications that is used, these conventional proxy models can only provide, at best, responses at the well locations, i.e. pressure or rate profiles at the well.
In this paper we present application of a new approach to building proxy models. This method has one major difference with the traditional proxy models. It has the capability of replicating the results of the numerical simulation models, away from the wellbores. The method is called Grid-Based Surrogate Reservoir Model (SRM) since it is has the unique capability of being able to replicate the pressure and saturation distribution throughout the reservoir at the grid block level, and at each time step, with reasonable accuracy. Grid-Based SRM performs this task at high speed, when compared with conventional numerical simulators such as those currently in use (commercial and in-house) in our industry.
To demonstrate the capabilities of Grid-Based SRM, its application to three reservoir simulation models are presented. Fist is a giant oil field in the Middle East with a large number of producers, second, to a CO2 sequestration project in Australia, and finally to a numerical simulation study of potential carbon storage site in the United States. The numerical reservoir simulation models are developed using two of the most commonly used commercial simulators1. Two of the models presented in this manuscript are consisted of hundreds of thousands of grid blocks and one includes close to a million cells. The Grid-based SRM that learns and replicates the fluid flow through these reservoirs can open new doors in reservoir modeling by providing the means for extended study of reservoir behavior with minimal computational cost. Surrogate Reservoir Modeling (SRM) is classified as an AI-Based reservoir model (Mohaghegh, 2011) referring to a process that accomplishes the task of proxy modeling by learning the specific behavior of a numerical reservoir simulation model through training on a uniquely developed spatio-temporal dataset. The spatio-temporal dataset is developed for each model using only a handful of simulation runs.
Leveraging New Technologies To Expedite Thermal EOR Facility Expansions
Authors: Kovac Hannie , Malpiede Neil 
Published: March 2012

Abstract
Redeveloping a heavyoil field is a complex undertaking. It requires a thorough understanding of the geology, reservoir and fluid characteristics, and the existing facilities infrastructure. Redevelopment should progress with minimal interference to existing facilities operations, maximizing positive cash flow from beginning of work to full commissioning of the new facilities. Employing new technologies and techniques in design, fabrication, installation, commissioning and start-up can help accomplish a successful expansion of an existing plant. Always, the objectives are to maximize safety, assure best operability, maximize efficiencies, provide design flexibility, ensure best fit of design to the redevelopment plan, and ultimately provide satisfactory project economics.
A comprehensive baseline of the existing infrastructure is required as a basis for process expansion. The 3D Scanning methods presented in this paper provide an efficient method of precision baselining existing facilities. Critical tie-in points are identified on 3D models. Equipment sizing and selection are influenced by the available footprint, access, and utility infrastructure – often undocumented in older facilities that have undergone numerous modifications. Emphasis is placed on minimizing interference with existing production equipment. The tie-in points identified using 3D scanning are integrated into the piping design process. The operator has the opportunity to "fly" through the proposed design and evaluate operability in a very effective three dimensional viewport. CAD (Computer Aided Design) drawings from 3D models allow precise dimensioning of pipe spools and allow off-site fabrication of tie-in spools. The tie-in points are installed in a shorter shutdown and are fitted with the isolation required to bring the process online without taking additional downtime. The net benefit is reduced exposure; fewer contractors working on location, fewer and shorter turnaround outages, and a better operational functionality review of the design prior to implementation – resulting in a safer, faster, and higher integrity project overall.
Type Curves for Pressure Transient Analysis of Composite Double-Porosity Gas Reservoirs
Authors: Rana Sachin , Ertekin Turgay 
Published: March 2012

Abstract
This paper presents a new set of type curves for pressure transient analysis of composite dual-porosity systems. The composite, double-porosity system studied in this paper represents shale gas reservoirs with multistage hydraulically fractured horizontal wells. Upon hydraulic fracturing of horizontal wells, it is critically important to determine the permeability and extent of artificially induced fractures. In this study, it is shown that these properties can be calculated by using the type curves presented in this study. In addition to the permeability and extent of hydraulic fractures, dual-porosity dimensionless parameters of the hydraulically fractured region can also be calculated using these type curves. It is shown that type curves developed in this study provide accurate results via analysis of the pressure transient drawdown data. A case study is presented to validate and show the application of the type curves.
Reference Model of Project Prototyping Problem
Authors: Relich Marcin , Banaszak Zbigniew 
Published: March 2012

Reference Model of Project Prototyping ProblemThe paper presents the idea of reference model of project prototyping problem for the projects that are at risk of failure. The hierarchical structure of declarative model connects two fields: functionalities of a typical service enterprise and management system of project execution in the enterprise. The functionalities as separate Constraints Satisfaction Problems (CSP) are described. CSP contains the sets of decision variables, their domains and constraints, which link these variables. The separated problems described as CSP, then in single main CSP are integrated. On the other hand, these problems can decompose into the subproblems concerning the functionalities of different fields. The open structure of model enables to solve the decision problems with different level of specificity. The decision problem can regard a query about the results of proposed decisions as well as the decisions guaranteeing the expected results. A declarative kind of proposed reference model in a natural way allows to implement its in constraint programming languages. The possibility of this approach illustrates an example.
Complex Mathematical Models for Analysis, Evaluation and Prediction of Aqueous and Atmospheric Environment of Latvia
Authors: Guseynov Sharif , Kopytov Eugene 
Published: March 2012

Complex Mathematical Models for Analysis, Evaluation and Prediction of Aqueous and Atmospheric Environment of Latvia
In present paper the authors consider the complete statements of initial-boundary problems for the modelling of various aspects of aqueous (3 models) and atmospheric systems (2 models) in Latvia. All the proposed models are described in terms of differential equations theory (using both ordinary differential equations and partial differential equations) and are regarded to be the evolutional models. Two of the three aqueous system models being studied are intended to describe the natural aquatic media ecosystems while the other models are aimed at studying environmental pollution processes.