bluuebunny/crossref_metadata_2025_split huggingface dataset:
Solid and Soluble Products of Engineered Water/Rock Interactions in Eagle Ford Group Chemofacies
Authors: Zhang Lifu , Tice Mike , Marcantonio Franco , Hascakir Berna 
Published: October 2017

Abstract
Interactions between reservoir rocks and engineering fluids during hydraulic fracturing have potential for modification of pores and flow paths by mineral transformation and precipitation and contamination of production fluids by metals and other salts. In order to infer how these interactions affect hydraulic fracturing performance, this study investigates interactions between engineering water and reservoir rocks from different chemofacies in Lower Eagle Ford Group under relevant temperature and pressure conditions. Rock samples were selected from five chemofacies in Lower Eagle Ford Group, which were divided by variations in different element concentrations and total organic carbon (TOC). Static and dynamic experiments were conducted at different condition. In static experiments, crushed reservoir rock samples were exposed to deionized water for three weeks at room condition. In the dynamic experiment, deionized water was continuously injected to the experimental system for three hours at reservoir condition. Rock samples were characterized by XRF before experiments to estimate major and trace elemental concentrations. Water samples after experiments were analyzed for ion contents, total dissolved solids (TDS), particle size and zeta potential. ANOVA single factor analysis using Tukey HSD and principal component analysis (PCA) were used to assess the similarity and difference in interactions between chemofacies. Water parameters were used to determine the tendency of suspensions to precipitate and potential to modify flow pathway during hydraulic fracturing.
This study provides information on interactions likely forming between water and Eagle Ford reservoir rocks and key geochemical tracers indicative of the effective surface areas where interactions occur. The information enhances the understanding of water-rock interaction mechanisms and distribution of fracture networks.
Enhanced Oil Recovery - Polymer Flooding: Surface Transfer Facility Design, Graphical Approach for Hydraulics and Tackle Induced Vibrations
Authors: Jain Shagun , Parekh Bharat 
Published: October 2017

Abstract
Cairn Oil & Gas, vertical of Vedanta Limited, has implemented one of the largest Enhanced Oil Recovery Process (Polymer flood) for its Mangala field (in Rajesthan block) to accelerate and increase the oil recoveries. The Mangala EOR project is a project of national strategic importance which is expected to produce an incremental 74 million barrels till 2040, a six per cent growth over the existing ultimate recovery projection. Based on the positive response of the EOR in the Mangala field, Cairn plans to extent EOR - polymer flooding process to other fields. The reservoir quality, drive mechanism, oil properties make these fields ideal for the application of chemical flooding EOR methods. Due to high viscosity contrast between oil and water, the injected water is unable to displace the oil very efficiently, resulting in some bypassed oil under a conventional water flooding scheme. By adding polymers, the injected water attains a viscosity close to that of the oil, which improves the displacement and overall sweep.
The paper identifies and covers several facets, crucial while designing surface facility for implementing EOR-polymer flooding in a field. The objective of the paper is to Validate and assess theories on pressure and temperature drop estimation for Non-Newtonian fluid with field observations.Present novel models for catering out hydraulics of the Non-Newtonian Polymer Solution. These models have been specifically developed to meet the requirements for plant design while taking into account uncertainities related to actual EOR projects.Present challenges faced in piping system post commissioning of one of the world’s largest full field polymer flood implementation. Root cause analysis of the problem and lessons learned for designing piping systems.
Lean System Aids in the Selection of an Engineered Elastomer/Stator Configuration Leading to Improved Downhole Performance and Field Economics
Authors: Gauthier J. , Grimes M. , Rebellon J. E. , Brown A. 
Published: October 2017

Abstract
Today's demanding market conditions require a higher level of performance in drilling operations to maximize return on investment. This case study outlines how an Operator utilizing the Lean Management System was able to capture and identify non-value added (waste) activities in the drilling process. Thus the Operator was able to single out components in the drill string which generated the largest number of incidents leading to rig non-productive time (NPT). This study led to the identification of a product in the marketplace that helped substantially reduce NPT (waste elimination), positively impacting operations.
Historical run data for each drill string component was tracked, allowing the engineering team to clearly identify the largest number of failed components and root cause for each incident. Data covering a 6-month span indicated 48% of downhole mud motor failures were attributed to power sections. In conjunction with the Lean System, the application of Hierarchy of Controls enabled the Operator to systematically find a corrective action through substitution and engineering controls.
In US shale plays like the Eagle Ford, Haynesville, and Bakken, there is a demand for improved product performance due to challenging drilling applications where bottom-hole temperatures push the limits of existing downhole mud motors. To address these concerns, a new power section with an elastomer capable of withstanding these harsh environments was identified. This paper will compare 100 Eagle Ford shale wells drilled with and without this new elastomer. Designed with a new chemical composition, the trial elastomer led to enhanced performance, including a 65% improvement in success rate and an increase in overall ROP of 21%. The close collaboration between the engineering teams incorporating de-rating performance tables and operational recommendations led to immediate results in the field. This step change in drilling performance led to substantial economic benefits for the Operator.
Identification of Optimum Closure Relationships for a Mechanistic Model Using a Data Set From a Low-Liquid Loading Subsea Pipeline
Authors: Roullier David , Shippen Mack , Adames Pablo , Pereyra Eduardo , Sarica Cem 
Published: October 2017

Abstract
Multiphase flow mechanistic models are macroscopic conservation equations (mass and momentum) supported by several empirical closure relations. There are several empirical corelationsavailable for each closure relationship. The success of mechanistic models largely depends on the employed closure relationships. Although, ideally, the closure relationships are desired to be applicable for all operating conditions and fluids;however, in reality, it is difficult to find such universal closures due to empiricism involved in the development of the closureships. Until the development of universal closure relationships, another viable approach is to find different set of closure relationships for identifiably different flow conditions such as low liquid loading flow or high viscosity liquids.
In this study, we present a procedure to test the performance of multiple closure relationships against available databases. As an initial application of the procedure, we have tested different combination of closure relationships in the Unified Model (Zhang et al., 2003) and identified the combinations of closures that produce the best model performance for low liquid loading conditions using the field data set consisting of the nineteen field measurements from Frigg to St. Fergus gas and condensates export line. The results of the 37,620 simulations were analyzed. The results showed that the original set of closure relationships used in Zhang et al. (2003) was not optimal for this particular set of data. Instead, a different set of closure relationships is proposed to improve the model's performance for these specific field cases. Total absolute average pressure drop deviation was reduced form 11% to 10%. Total absolute average liquid content deviation was reduced from 66% to 1%. Using the proposed procedure, with the availability of additional large-scale field data, the set of closure relationships can be further refined, and even the elusive goal of finding universal closure laws would be possible.
Generalized Multiscale Coupling of Triple-Continuum Model and Discrete Fracture Network for Carbonate Reservoir Simulation
Authors: Wang Min , Wei Chenji , Song Hongqing , Efendiev Yalchin , Wang Yuhe 
Published: October 2017

Abstract
In this paper, we couple Discrete Fracture Network (DFM) and multi-continuum model with Generalized Multiscale Finite Element Method (GMsFEM) for simulating flow in fractured and vuggy reservoir. Various scales of fractures are treated hierarchically. Fractures that have global effect are modeled by continua while the local ones are embedded as discrete fracture network based on the geologic observation. For independent vugs, a continuum is used to represent their effects with specific configuration that there's no intra-flow of this continua. GMsFEM enables us to systematically develop an approximation space that contains prominent sub-grid scale heterogeneous background information based on the multi-continuum and DFM model. Conforming unstructured mesh is used to surrender the application of random discrete fracture networks. This paper targets on the improvement of the flow simulation performance in complex high-contrast domain by extending the ability of multiscale method to modeling arbitrary discrete fracture network. This advancement by GMsFEM is motivated by the limited capability of Multiscale Finite Element Method (MsFEM) on modeling discrete fractures when multiple fracture networks present in same coarse block. Multiple numerical results are shown to validate the efficiency of our coupled method.
Designing Subsea Production Systems for Efficient Startup to Mitigate Costly Topside Downtime
Authors: Chidiac Cedric , Sauvé Robert , Kunz Sarah 
Published: October 2017

Abstract
Starting up a subsea production system for large offshore developments is a time-consuming task that can take multiple hours or days. The startup is particularly inefficient during an unplanned shutdown, where the operator may have a threshold time (e.g., 4–6 hours) to fix the problem and startup the production system, before having to preserve the field.
The workflow discussed in this paper aims to determine and reduce the startup time of a subsea production system (SPS). At the center of the workflow, a dynamic integrated model is used to accurately assess and effectively adjust scheduled startup time of the SPS. The integrated model evaluates the dynamic simulation response of a large field startup by integrating a reservoir and gathering network model. The overall workflow incorporates subsurface simulation model, equipment design, field layout design, control systems, and system constraints to create a complete field architecture capable of handling quick, efficient field startups throughout the field life.
The integrated workflow presented in this paper captures a full dynamic response, from the reservoir to the topside. Among other things, a full reservoir model has been integrated with a full dynamic network model that allows for startup evaluation and adjustment to be performed at different points throughout the field life.
Hydrate Induced Vibration in an Offshore Pipeline
Authors: Jujuly M. M. , Rahman M. A. , Maynard A. , Addy Matthew 
Published: October 2017

Abstract
Gas hydrate plugging is considered a very challenging issue in offshore petroleum production and transportation. The phenomenon of hydrate plug formation involves low temperature and high pressure condition. Hydrates can damage equipment of petroleum transport system. In this study, a computational fluid dynamics (CFD) model is proposed to analyze the effect of hydrate flow in pipelines using ANSYS FLUENT multiphase flow modeling techniques.
This study has been carried out with a joint industrial collaboration with GRi simulations, Canada. Two case studies have been investigated. The first one is with a pipeline with a dimension specified by an existing literature (Balakin et al., 2010a) for validating the simulation results. The other one is with a more complex geometry of M-shaped jumper including six elbows. Eulerian-Eulerian method was used to model the multiphase hydrate flow. Moreover, the population balance method (PBM) was used to model the hydrate agglomeration and breaking up mechanism. A parametric study of stress analysis due to the flow-induced vibration on pipelines was also investigated.
This study helps to identify the regions where the maximum stress and deformation due to various flow conditions. The overall objective is to integrate the ANSYS FLUENT model with GRi simulation's IDEA-FDK platform. Petroleum industry can effectively use the proposed tool to prevent the risky operating conditions in offshore structures. The results from the analysis will help to identify the cause of the pipeline failure, regions of the maximum stress occurred in the pipeline and the plastic deformation of the pipeline due to hydrate flow in pipeline.
Delivering Better Business Outcomes with Soft Skills
Authors: Howes C. Susan , Dalrymple Lori , Nelson Jon , Solomon Greg 
Published: October 2017

Abstract
It has often been said that "Technical skills get you hired, and soft skills get you promoted." Whether they are called "soft skills," "nontechnical skills," or "professional skills," the incorporation of soft skills into the development of technical professionals is evolving and becoming more critical to both employers and technical professionals. Because of the "Big Crew Change," new supervisors and technical leaders will take on new responsibilities, which will require them to rely upon their soft skills. Ensuring that soft skills training is embedded with technical training prepares future leaders.
The quality of the technical contribution increases when individuals work more collaboratively. Soft skills help to improve personal effectiveness, providing a vehicle with which to deliver business results. Soft skills enhance expected business outcomes of the technical professional's work product. A variety of methods are utilized in professional development to disseminate best practices in soft skills to technical professionals. In addition to SPE, several other professional and technical societies are placing an increasing emphasis on soft skills development.
There are several ways to measure the impact, both qualitatively and quantitatively, of incorporating soft skills into professional development for engineers. One way of measuring the impact includes surveying participants and their supervisors according to Kirkpatrick's levels of evaluation. It is challenging to incorporate soft skills development into existing rigorous engineering degree curricula or corporate onboarding programs without sacrificing the emphasis on development of technical competency.
Increasingly, it is becoming more apparent that the value of the effort to incorporate soft skills, pays off in multiple ways to both the corporation in achieving their strategic objectives and to the working professional in realizing their career development goals. Common themes from case studies, surveys and benchmarking with other professional technical societies will illustrate how to deliver better business outcomes with soft skills.
Real-Time Formation Evaluation and Contamination Prediction Through Inversion of Downhole Fluid Sampling Measurements
Authors: Kristensen Morten , Chugunov Nikita , Gisolf Adriaan , Biagi Mario , Dubost Francois 
Published: October 2017

Abstract
Acquisition of fluid samples using wireline formation testers (WFT) is an integral part of reservoir evaluation and fluid characterization. Recent developments in formation tester hardware have enabled wireline-based fluid sampling in a wide range of downhole conditions. However, accurate quantification of oil-based mud (OBM) filtrate contamination using data from downhole fluid analysis (DFA) sensors alone remains challenging, especially in difficult sampling environments and for advanced sampling tools which have complex inflow geometries and active guarding of filtrate flows. Such tools and conditions lead to contamination behaviors that do not follow simple power-law models which are commonly assumed in OBM contamination monitoring (OCM) algorithms.
In this paper, we introduce a new OCM algorithm based on inversion of DFA data using a full 3D numerical flow model of the contamination cleanup process. Based on formation and fluid properties and operational tool settings, the model predicts the evolution of filtrate contamination as a function of time and pumped volume and can thus be used to forward-model the DFA sensor responses. Sensor data are then inverted in real time to provide contamination predictions. Real-time computation is enabled through fast, high-fidelity proxy models for the cleanup process. The proxy models are trained on and thoroughly vetted against a large number of full-scale numerical simulations. Compared to existing algorithms, the new OCM method is now applicable for all types of sampling hardware and a wider set of operating conditions. By directly relying on a model of the cleanup process, the physical properties of the formation and fluids (such as porosity, permeability, viscosity, and depth of filtrate invasion) are estimated during the inversion, thus providing additional valuable information for formation evaluation.
The new method is demonstrated by practical application in both synthetic and field examples of oil sampling in OBM. The synthetic examples demonstrate the robustness of the algorithm and show that the true formation and fluid properties can be recovered from noise-corrupted sensor data. The field example presented demonstrates that contamination predictions are in good agreement with results from laboratory analysis, and the inverted formation properties are consistent with estimates based on openhole logs and pressure measurements.
Unconventional Completions Optimization in the Upper and the Lower Montney Formations, Canada
Authors: Mohammed Omar Q. , Kassim Rashid , Britt Larry K. , Dunn-Norman Shari 
Published: October 2017

Abstract
The Montney Formation which stretches from Alberta to British Columbia is one of the largest unconventional gas resources in North America. Production from the Montney Formation comes primarily from the Upper Montney and Lower Montney Formations which vary both from reservoir quality and geomechanical perspectives. Historically, completion and stimulation optimization fell into two distinct categories (1) field observation supported by reservoir and fracture simulation or (2) statistical analysis. Few, if any, statistical studies on optimizing unconventional completions and fracture stimulation combined information from the statistical analysis with that of the simulation. This paper does just that for the Montney Formation by comparing and contrasting the Upper and the Lower Montney completions and fracture stimulation statistical results with a reservoir and fracture simulation study to better understand key drivers for successful stimulation of multiple fractured horizontal wells.
Previous work (Mohammed et al. 2016) documented the statistical analysis of 296 cased-hole horizontal gas wells' completions in the Upper and the Lower Montney Formation. The study showed the effect of cased-hole completion and stimulation parameters on gas production performance in both the Upper and the Lower Montney Formations. In this paper, previous statistical results were extended by adding hydraulic fracture modeling using 3D finite element simulator. The results from the statistical analysis and hydraulic fracture modeling were compared on a set of parameters such as the effect of the number of clusters per stage (1-to-5), changes in proppant mass (50% decrease or increase) and treatment volumes. The results also show the effect of cluster spacing and proppant type on fracture dimensions and production performance within the Upper and the Lower Montney Formation.
This study investigated fracture performance to find the best fracturing practices for the Upper and the Lower Montney. This wok benefits the industry by: Providing a solid simulation study of horizontal gas wells with cased-hole completion, which compared fracture performance for the Upper and the Lower Montney Formation.Providing comparison of multiple fractured horizontal wells' performance in the Upper and the Lower Montney Formation based on the number of clusters per stage and treatment volume.Identifying factors that affect cased-hole completions and stimulation performance in the Upper and the Lower Montney Formation.By conducting fracture cluster optimization study to determine the effect of the number of clusters, cluster spacing and proppant type on fracture dimensions and well performance.
Mono & Thin Layer Performance of Small Mesh Size Proppants Placed in Horizontal Well Fracture Matrices
Authors: Herskovits Raphael , Kidd Ian , Fuss-Dezelic Tihana , Shi Jingyu , Wilcox Craig , Kaul Todd 
Published: October 2017

Abstract
Today unconventional completion objectives strive toward three major goals: creating large fracture networks, placing as much proppant in those networks as efficiently as possible and ensuring fracture conductivity is sufficient to allow for maximum reservoir drainage. While operators use different, and often proprietary, completion protocols to achieve these goals, market research shows a growing trend towards the use of small mesh size proppants such as 30/50, 40/80 or even 100 mesh proppants primarily utilizing slickwater fracturing fluid systems.
Fracturing of unconventional reservoirs in this manner creates a very narrow fracture environment. This creates a completion design problem as most proppant types and sizes are qualified using 2 and 4 lb/ft2 loading conditions to simulate the wider fractures of conventional sandstone reservoirs. Further complication also lies in the fact that prior to shale development, small mesh size proppants, such as 100 mesh were very rarely used or tested as a proppant.
The study compares the mechanical strength of 40/80 white sand, 40/80 clay-based economy lightweight ceramics (ELWC) and 40/80 bauxite-based intermediate strength ceramics (ISC), as well as, 35/140 bauxite-based intermediate strength ceramic (ISC) and 100 mesh sand using standard and modified API RP 19-C crush resistance tests. During testing, load cell concentrations were varied from the standardized 4 lb/ft2 to the modified concentrations of 0.5 and 0.25 lb/ft2 – concentrations more realistic for unconventional reservoirs. Mechanical failure of proppants is quantified by comparing proppant size distribution pre- and post-stress application using a Horiba CAMSIZER. Mechanical compression of proppant packs is measured during testing and compared for different proppant types. Failure mechanism of proppants is also evaluated using an in-situ high pressure CT scanning protocol enabling visualization of the proppant failure as a function of applied load, proppant type and concentration.
The study shows that mechanical performance of tested materials, measured as proppant crush, deteriorates with decrease in proppant bed height. Deterioration of performance is, however, much less pronounced for small mesh size proppants than previously studied large mesh proppants. Contrary to that, pack compression results indicate higher compression of small mesh proppants under monolayer/thin bed conditions suggesting a large decrease in proppant pack conductivity. The most extreme pack compression is measured for 100 mesh sand proppants. In-situ CT scans also confirm these results and further visualize the effect of pack compression on proppant pack conductivity.