bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluation of Different Types of Operation for Inflow-Control-Valves Based on Production and Reservoir Data
Authors: Barreto Carlos E. , Botechia Vinícius E. , Schiozer Denis J. 
Published: June 2014

Abstract
Intelligent valves provide more flexibility for well operation and different options to improve field production. The number of control alternatives is large and the decision of using inflow-control-valves is not simple, mainly for choking valves. Therefore, it is necessary to quantify economic and technical impacts in order to avoid undesired results. This work uses reservoir simulation to evaluate valves operation as the basis for the decision-making process. The process is based on simulation results to quantify real-time production and reservoir data on the short and long-term effects. Observed data, such as water breakthrough, water front movement and production economic limit are used to make control decisions. A test example is created to represent a fracture region of a reservoir with channel configuration; then, different reservoir size models and different well production constraints are created. The results show that actions to control water front and to shut down regions in which the breakthrough occurs, significantly increase the NPV. Conversely, attempts to control water front and breakthrough in cases in which the production rate is not constrained may lead to a significant NPV reduction without providing any significant increase in oil recovery. It is also shown that it is essential to shut down regions where the production economic limit is reached, even if a higher oil recovery factor can be achieved. As a conclusion, inflow control valves operation based on real-time production and reservoir data may efficiently improve field production when an adequate control is applied. The decisions are complex and must be made carefully, observing the real-time data and associated limiting conditions. This paper provides information that supports the use of water front movement, water saturation and production data to operate inflow-control-valves. It is proved that the use of the production and reservoir data considered in this work can help real-time operation to achieve relevant long-term effects. However, it is important to observe reservoir conditions to make an adequate use of data.
Novel Gas Shutoff Resin System for Well Abandonment Applications in Colombia: A Case History
Authors: Urdaneta J. A. , Arroyave J. M. , Jones P. , Amaya J. L. , Coral A. , Hernandez H. 
Published: June 2014

Abstract
Recent studies have shown an increase in the percent of wells affected by sustained casing pressure over time. Both the oil and gas industry and governments are studying the causes of sustained casing pressure and methods to help prevent undesired flow that can potentially result in the loss of wellbore integrity and environmental problems.
In the Caribbean region in northern Colombia, various natural gas production fields have been developed for decades. Because of mechanical problems or low economic return rates, some producing gas wells have been abandoned. Some wells in this area have been abandoned using conventional cement techniques without success, sometimes resulting in gas communication through the annulus to the surface. This has even been observed in some cases where the primary top of cement (TOC) was planned to surface. Potential gas communication through the wellbore annulus has been an issue in the industry for a long time. There are several factors influencing gas communication, such as flow through mud channels, micro-annuli, and flow through unset cement, among others.
This paper presents the successful application of a new resin with superior mechanical properties and solids content designed according to the needs of the well, which allow it to penetrate areas previously inaccessible to conventional cement slurry, such as small fractures, channels, or micro-annuli. The case study presented shows how a sustained casing pressure problem was caused by a channel in the primary cement job. The novel resin system was pumped successfully as a squeeze job ahead of neat cement slurry to isolate the gas-producing formation, and no further gas production was observed at surface, bringing the well back into compliance with government regulations for proper well abandonment.
Increasing the Efficiency of Artificial Lifting System in the Production of Heavy Crude: A Colombian Field Application
Authors: Jaimes M. G. , Pachon Z. , Villar A. , Dorado R. 
Published: June 2014

Abstract
The light crude reserves are increasingly scarce and every day there are new discoveries of heavy oil. The heavy oil, extra heavy and bitumen make up approximately 70% of total oil resources of the world, which focuses the attention of the industry in this type of oil. An adequate management of heavy crude oil production in mature fields requires optimizing the efficiency of artificial lifting systems (ALS), in order to increase the productivity of the assets at appropriate levels.
The main difficulty in the low efficiency of ALS in the production of heavy crude oil is the high friction pressure losses in the system due to high viscosities that are handled (greater than 1000 cp). The selection, evaluation and application of chemical treatments to reduce the viscosity of crude oil in down hole was visualized, in order to improve the efficiency and ensure the adequate conditions of extraction and recollection to maintain optimal levels of production.
This study presents a detailed assessment of mobility enhancing additives (MEA) in fields operated by the Colombian state owned oil company, Ecopetrol, Which includes:
Characterization of the problem Selection of candidates State of the art of the MEA Characterization and Evaluation Methodology: Qualitative Evaluation, Rheological Behavior, Evaluation in the capillary viscometer Evaluation of compatibility with the additives added in the extraction, recollection and treatment system. Selection and Evaluation of treatment at different conditions of temperature, Shear Rate, percentage of water in emulsion Effect of viscosity in the efficiency of ALS (optimum range of operation) Nodal analysis to determine incremental production Evaluation of the technical and economic benefits.
This paper presents the application results in an Apiay oilfield well, in Colombia.
Finally, conclusions, recommendations and field results obtained in this study are presented and among which are: Increased of the efficiency of the ALS in 30%.Increased of oil production in 50%.Profit of USD $1, 000, 000 for implementation of the MEA in the Apiay Well.
Improving the Performance of Steam Drive in Channeled Heavy Oil Reservoirs: A Global Optimization Strategy
Authors: Awotude Abeeb A , S Azad Madhar , Naranjo Suarez C E 
Published: June 2014

Abstract
The thermal methods commonly applied in developing fairly homogeneous heavy-oil reservoirs may not be viable options in channeled heavy-oil reservoirs mainly because the injected fluid (steam) would bypass the heavy oil by flowing through the high permeability channels. Experimentally, it was found that the key to success in developing such reservoirs is to have optimum heat conduction which overcomes the reservoir heterogeneity. Hence, steam flooding, if properly optimized, could overcome this problem. Injection rate and steam quality are the main operational parameters that controls the economic heat propagation in the reservoirs. Additionally, placing the wells in more conducive areas to ensure that the regions with low-to-medium permeability get enough heat, is crucial.
In this work, we propose the optimization of steam quality using CMA-ES. A three-dimensional channeled reservoir model undergoing steam flooding was built and CMA-ES was used to estimate the optimal values of three variables of steam flooding. The Net Present Value (NPV) of the project was used as the objective function and three cases of optimization were studied. In Case 1, only the injection and production rates were optimized. In Case 2, well placement was optimized along with the rates. In Case 3, steam quality was included in the list of optimized variables. Results indicated that Case 2 gave higher NPV than Cases 1 and 3 signifying the importance of optimum selection of well placement. Also, it is understood that steam quality is an important parameter which controls the overall steam flooding process and a large number of function evaluations is required to obtain optimum values of steam quality.
Stochastic Sensitivity Analysis for effective Parameters Ranges on 3D Fracture Network Using Stress Distribution, Outcrops and Wellbore Data Adjusted to Well Production History in Mature Field
Authors: Bustamante E. J. , Cabello Rios V. , Escobedo Cabrera D. , Manrique Cáceres P. , Choque L. , Espíritu W. T. 
Published: June 2014

Abstract
The Mogollon Formation of the lower Eocene is among the most productive of the Block X that is located on the continental shelf along the northem coast of Peru. The Mogollon Formation is considered a Natural Fractural Reservoir that has been produced for 50 years; because of the age of the wells, they have not image log information even more the study area does not have seismic information; therefore, these lacks of data does not allow characterizing appropriately the fracture distribution and its impact on the production.
Previous studies tried to establish a methodology to characterize fracture sets but not reached to establish a proper relationship with production.
The aim is the stochastic Sensitivity Analysis to find effective parameters ranges on 3D Fracture Network using information of Stress Distribution, Outcrops and Wellbore Data adjusted to well production history in the mature field, 50 Wells were used in the study.
The Methodology consists in finding the ranges of variation of the indicators of fractures which are fracture density, aperture, orientation, length, distribution on the fracture site and configuration strain studies, which are obtained from a few available core data and outcrops; ranges allowed to develop a stochastic model with multiple realizations which were simulated numerically to find the best fit with the production history of the zone.
The study allowed establishing drainage preferential direction and 10 blocks with the same conditions was extrapolated. This methodology was incorporated in reservoir studies performed in the drilling project in the Block.
Computational Fluid Dynamics For Estimating Oil-Water Relative Permeability Curves
Authors: Cuevas J. , Gasbarri S. , Asuaje Miguel 
Published: June 2014

Abstract
Reservoir simulation is essential for defining the best exploitation and production strategy during different stages of development in a hydrocarbon field. The phenomenological understanding of fluid dynamics within the porous media is vital for reservoir engineers. The more accurate the permeability curves, the better the planning for exploitation. Several analytical and experimental techniques are used to determine the permeability curves with the least amount of associated uncertainty. Sometimes they have high degrees of complexity and cost, using direct and indirect methods in which the scale ranges from microscopic to macroscopic.
CFD has been moderately used in the oil industry for mechanical modeling of sand and Cutting Transport in Wellbores. It has also being used in the design and development of new drill bits and Inflow Control Devices (ICDs). The potential of using these packages in microfluidics studies (Glatzel 2008) has been shown recently.
This study provides evidence of the feasibility of using CFD for fluid flow modeling through a specific-shape porous media so core plug experiments may be optimized. Through this modeling, the relative permeability curves for oil and water in a porous medium can be estimated. The system was modeled in a rhombohedral-packing geometry with dual-sphere array. It was tested for different multiphase models available. A quantitative comparison with analytic-experimental models shows excellent results. The simulated displacement of the fluids is qualitatively comparable to those reported by visual experiments reported previously.
With little cost of money and time, this technique can be used for characterization of micro-phenomena within the porous media such as: Distribution of fluids in steady-state and transient processes (drainage and imbibition), Interaction of injection agents for improved or enhanced oil recovery, rock wettability and temperature effect on relative permeability curves, and nanotechnology applications.
Evaluation of Different Secondary Recovery Process in the Bachaquero-01 Reservoir
Authors: Rosal Z. , Mieres K. , Chourio G. 
Published: June 2014

Abstract
Since there are a lot of reservoirs of highly viscous heavy oil, whose extraction is a challenge for petroleum engineers in Venezuela, and also the significant gas shortage, which makes many of the gas injection projects in our reservoirs in the west of the country have been suspended are reasons why it has raised the need to explore alternative sources for the recovery of such highly viscous oil.
Improved Recovery processes emerge as an alternative to increase hydrocarbon recovery, changing the characteristics of the fluids and the capillary forces acting on them. Enhanced recovery is mainly based on sophisticated techniques in operation, is usually costly, but very effective, therefore, the enhanced hydrocarbon recovery is defined as oil production, by injecting a fluid, in addition to displace oil, favorably modifies the oil recovery mechanisms. The techniques can be applied at any stage during the operation of the reservoir; in fact, there are formations which for its geological and petrophysical characteristics can only be exploited by Enhanced Recovery techniques. Several factors play a role in the selection of the most economically attractive alternative, these factors are: The rock type and characteristics that have the greatest influence on the pattern of exploitation is undoubtedly the porosity, permeability, reservoir fluid, and the last factor is the injection fluid to be introduced to the reservoir. The selection of the fluid to be injected either to maintain reservoir pressure, move, or modify the mobility of hydrocarbons, are carried out based on the analysis of the molecular interaction between the injected fluid and oil in a reserve.
The present study shows the results of the Evaluation of Different Secondary Recovery Process in Reservoir BACH-01 to increase the recovery factor of the same; this reservoir is located on Lake Lagunillas Exploitation Unit. It was built a numerical simulation compositional model using the simulator STARS of CMG company, to represent the geometry and dynamics of the reservoir fluid flow, thereby validating the rock / fluid properties. Among the different methods studied is the CO2 injection, the Alternating Steam Injection more Gas (IAV + GAS), SAGP y VAPEX.
Development of a Finite Element Computer Simulation Platform for a Coupled Reservoir and Geomechanics System
Authors: Morillo A. , Moreno J. , Quintero R. , Gambús M. , Zambrano O. , Marcano V. , Araque J. , Rincón N. , El Mejmissani N. , Guíñez J. , Pirela M. Perez 
Published: June 2014

Abstract
The aim of this article is to describe the development of a finite element computer platform for the modeling, analysis, and simulation of a coupled reservoir and geomechanics system. The conditions that are assumed are the simplest possible, so that we assume homogeneity and isotropy in the material, an elastic behavior of the rock with small deformations, a quasi-static equilibrium, the absence of fractures and isothermal state. The study evolves sequentially in stages, from the flow of a single fluid in a porous medium, through the two-phase case, up to the three-phase black oil model. The starting point is based on a mathematical model that is an extension of Biot's theory for flow in porous media, and which accounts for coupling the reservoir of fluid flow to the rock deformation and stress states. The mathematical model is reformulated in variational terms, in order to get a proper formulation that enables us to apply the weighted residuals methods of Galerkin with linear interpolation functions. The use of linear interpolant functions reduces the computational work but at the cost of having to face some inestabilities in the solutions. Once the model is discretized, we make use of appropriate software to built an unstructured meshing domain using tetrahedral elements. We carried out a computational model founded in the design of a program based in the C++ language, to perform the tasks of numerical calculations of the coefficients, assembling the stiffness element by element matrices, and for solving the resulting equations. It is intended to develop the computer program in a modular structure, so that the solution of the coupled geomechanics/reservoir system can be performed through an iterative procedure. The development of this code is still in its initial stage, but the approachs show promise. At the end two case studies are presented, which are compared with analytical solution for verification of the approach
Early Detection and Diagnosis of Operating Events in Real-Time for Producing Wells With Artificial Lift Systems With Submersible Pumping
Authors: Mejía J. A. , Gutiérrez C. A. 
Published: June 2014

Abstract
The rise of automation technologies has enabled storage and sensing of operational data in real-time for key variables in oil production wells. These data are a key component in decision-making in the operation and control of the production of the field, if they can be converted to timely and reliable information.
This paper focuses on the early detection and diagnosis in real time of operating events mainly by the presence of gas and solids that negatively impact the well production. Expert systems techniques for the characterization of reference operational events are used. They are based on known rules of behavior of electrical and mechanical operating variables, constructed by combining knowledge of the phenomenon and empirical data.
The matching of behavior of real-time operational variables processed by techniques of statistical process control - SPC together with reference events determine the presence of operational problems by generating real-time alerts that allow it to act in a timely way and mitigate the negative impact on the production of hydrocarbons from the oil fields.
Early detection algorithms and real-time diagnostic operational events were programmed in a software tool for real-time processing, which was applied to the monitoring of two case studies in wells Castilla and Guatiquia operated by Ecopetrol SA in Colombia. Finally the main findings, conclusions and recommendations from this study are submitted.
Optimizing Waterflooding Process for Recovery Using Nonlinear Model Predictive Control: Case Yariguí - Cantagallo
Authors: Prada Mejía J. A. , Osorio Suárez J. P. , Camacho Navarro J. 
Published: June 2014

Abstract
This paper describes the results of applying a strategy of nonlinear model predictive control (NMPC) for closed-loop optimization of the water flooding process simulation on a reversed pattern of 5 wells in the field YARIGUÍ –CANTAGALLO operated by Ecopetrol SA in Colombia.
Field modeling and predictions are made through the use of a commercial reservoir simulator. The solution of the optimization problem of nonlinear control loop is determined using an approach that uses the reservoir model as a black-box by looking for patterns and sequential algorithms.
To manage the information of operational variables required by the optimization strategy, an interface was developed by managing online the output files of the commercial simulator. NMPC algorithm stability is achieved by finding sub-optimal solutions of the optimization problem.
The robustness and performance of the NMPC strategy is illustrated by its implementation to optimize the water flooding process simulation represented by a model with 814.226 cells of which 352.034 are active, 199 layers, 38 failures, 26 areas of balance and heterogeneous distributions of permeability and porosity. Thus, by appropriate adjustment of the water flow rates, it is proposed to increase the production of oil for the case study. Finally the main findings, conclusions and recommendations from this study are submitted.
The Stratigraphic-Sedimentology Model of Upper Cretaceous to Oil Exploration Field "Campeche Oriente"
Authors: Cervantes A. , Gonzalez L. Montes 
Published: June 2014

Abstract
The main objetive of this job is elabotared "The Stratigraphic-Sedimentology Model of Upper Cretaceous to oil Exploration Field, by use of the deposicional characteristics, this reservoir rocks and advanced techniques to estimate the Original Oil in Place (OOIP) and associated reserves. For this field, the total area is 1282 km2 and consists of thirteen exploration field. The Upper Cretaceuos (Upper Breccia) is the principal reservoir rocks for their petrophysical properties (Naturally-fractured reservoirs), área and thickness. The total average porosity is from 8% to 10% with average thickness of 11 to 105 metros, thinning to the south-west. The model sedimentology is interpretation as the grains flow and debris flow or mudflow unto seafloor, on the edge of a carbonate platform, limestone naturally-fractured and Breccia in-situ. In these units, the brecha is defined for outer-platform (island-reef-shoal cycles) and talud, and fragmental material, observed in the stratigraphic columns, also they can come from the event castrastofy Chicxulub.
The used workflow goes from the structural modeling (147 fault), the size of the grid 500*500 (semi-regional model), 3 seismic horizonts in deep (Breccia, Upper Cretaceuos, Middle Cretaceuos). The facies definition was two: submarine fan and Stratified sediments using formation micro imager (FMI) of 21 wells drilled. The detritus flow "Apron" are submarine fan, the geometrical form is minor width, mayor width and orientation.
The well to well is not possible correlation this submarine fan because the depositional time are different and can be related to several factors: (1) accommodation space (space available for sediment to accumulate, which relates the position of sea level relative to the flooded preexisting sediment surface or sea bottom), (2) rate of sediment accumulation, (3) rate of base-level change, (4) slope of the flooding surface, (5) mechanical sediment and diagenetic compaction, and (6) isostatic, thermal-tectonic, and active-fault subsidence [see also Kendall and Lerche (1988)].
Consideration to several factors for the geometrical body was used workflow with polygons and probability map. This skill helps us to generate a model probabilistico of the submarine fans.
Uncertainty Analysis and Risk Assessment Methodology in Early Development Fields
Authors: Salinas R. , Di Nezio A. , Huerta V. 
Published: June 2014

Abstract
The development of a new field requires a special effort to recognize and evaluate static and dynamic reservoir uncertainties. Since there is limited information of the fields during exploration and appraisal phases, reservoir modeling is such a challenging task towards managing uncertainties and assessing the risk associated to it. The first step towards managing reservoir uncertainties is to identify and rank key reservoir parameters affecting hydrocarbon in place and recovery factor; then, key variables impact should be quantified by tornado or Pareto plots.
The current study gives an approach about Petrel™ tools in order to perform sensitivities and uncertainties analysis to some parameters; therefore, obtaining a reliable variation range of main outputs in this evaluation; in addition, achieving an indicator of main variables that affects the original volumes in place and recovery factors.