bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Framework for Compositional Simulation Using Reduced Order Modeling Based on POD-DEIM
Authors: Lee Jae Wook , Gildin Eduardo 
Published: July 2020

Abstract
Fast and reliable reservoir simulation is a key for the successful decision making in integrated reservoir studies. Large and complex multiphase reservoir models usually require expensive computational infrastructure. Physics-based model order reduction (MOR) methods have been introduced and applied (POD-DEIM, POD-TPWL), especially for mitigating the computational cost of black oil models in workflows that require multiple calls of the reservoir simulator. However, only a limited number of methods have looked deeper at the effectiveness of these techniques to multiphase and compositional simulation where expensive phase equilibrium calculations are added to the level of complexities associated with obtaining robust solutions. In this work, we develop the physics-based MOR techniques for rapid compositional simulations that accelerate calibrating of system of equations and phase equilibrium.
The combination of proper orthogonal decomposition (POD) and discrete empirical interpolation method (DEIM) has been used extensively in two-phase flow systems. POD reduces the size of the system to be solved, and DEIM contributes to approximate the nonlinear terms for faster computation. These snapshot-based methods work in a two-step process. In the training case one can obtain the snapshots, which are the solutions at each time step, to derive the POD basis and DEIM basis. Then the test case is utilized to validate if the reduced model works for the different well control schedule cases, and to compare the speed of the simulation run time.
Results show that the POD-DEIM technique enables us to approximate the conventional model with high levels of accuracy up to more than 99%. And it also enables a faster simulation owing to the reduced order system.
In this study, we show the robustness of POD-DEIM method to reduce the computational cost for multi-phase, multi-component 3D reservoir model.
Describing the Flow Behavior of Smart Water in Micromodels with Wettability Modified Pore Structures
Authors: Tahir Muhammad , Hincapie Rafael E. , Gaol Calvin , Säfken Stefanie , Ganzer Leonhard 
Published: July 2020

Abstract
This work focuses on oil recovery processes by smart-water injection in micromodels with different wettabilities. It provides detailed visualization of the displacements taking place during Smart-Water flooding at a pore scale level, whilst evaluating the effect of wettability on oil recovery. We propose a workflow for the evaluation of Smart-Water flooding including fluid-fluid and rock-fluid interactions. The methods studied comprise experiments with micromodels and core flooding. Artificial and real-structure water-wet micromodels (derived from Bentheimer sandstone material with three different permeability zones) were used to understand flow behavior and oil recovery. Subsequently, complex-wet and oil-wet micromodels helped understanding wettability and rock-fluid interaction. Synthetic-Sea-Water (SSW) was the benchmark fluid, and subsequently modified by diluting its composition. The effect of sulphate content in the brine was key in this work; polymer flooding was used as a final step to discard any possible further effects and as mobility control agent.
Micromodel experiments conducted in this work indicate that Smart-Water flooding performs better in mixed-wet (artificial structure) than water-wet systems, but with seemly good results for oil-wet systems. The observation slightly differs from core flood experiments, where oil-wet conditions provided a better process efficiency. Smart-Water flooding in artificial oil-wet micromodels led to higher produced oil compared to SSW injection in water-wet system. This behavior was expected, since the spiked sulphate present in Smart-Water disturbed the ionic equilibrium in the micromodel system causing a release of the polar compounds of oil. This is understood as an improved interfacial viscoelasticity at the oil-brine interface (fluid-fluid interaction), promoting additional oil production/continuous flow and ganglia movement. Results obtained in mixed-wet micromodel showed that when Smart Water is spiked with sulphate a 3.13% higher recovery is obtained compared to SSW. Same trend was observed for oil-wet micromodel with additional recovery of 2.63%. As an overall result, Smart-Water flooding recovered higher oil than the SSW injection in oil-wet and complex-wet system as compare to water-wet.
Majority of the work presented in the literature, have mainly focused on the evaluation of core flooding data for smart water injection. This work unlocks the potential of micromodels to study the micro-scale visual analysis of Smart-Water flooding through porous media. The workflow not only relies on oil-ganglia analysis and displacement efficiency evaluation, but also considers fluid-fluid and rock-fluid interactions.
A New Insight into Modeling of Polymer Flooding in Carbonate Reservoirs
Authors: Al-Shalabi Emad W. 
Published: July 2020

Abstract
Polymer flooding is a widely used chemical enhanced oil recovery technique in sandstones, but it has limited applications in carbonates. This is due to the harsh conditions of carbonates including high temperature, high salinity, low permeability, and high heterogeneity. Polymer flooding improves volumetric sweep efficiency through improving the adverse mobility ratio by increasing water viscosity. Therefore, the effect of trapping number on oil recovery is usually neglected. This paper numerically investigates the effect of trapping number on oil recovery by polymer flooding in carbonates under harsh conditions. The trapping number effect was predicted by running several 1D simulations using measured reservoir rock and fluid data. A previously history matched biopolymer rheological behavior was considered. This study aims to validate the flow behavior of this biopolymer through history matching recently conducted coreflooding experiments. Sensitivity studies were performed on different uncertain parameters to history match the oil recovery observed in the lab. These parameters include inaccessible pore volume (IPV), polymer adsorption, permeability reduction, shear rate coefficient, hardness of makeup water, and trapping number.
The results showed that IPV, polymer adsorption, permeability reduction, shear rate coefficient, and hardness of makeup water have negligible effect on oil recovery by biopolymer flooding. Also, history matching of oil recovery data was not possible when these parameters were varied within their typical range of values. Interestingly, when trapping number effect was applied through capillary desaturation curve (CDC), residual oil saturation was reduced to 10% as opposed to 20% without considering its effect. The pronounced effect of trapping number in this case is due to the increase in water viscosity post-polymer flooding compared to pre-polymer flooding, which is about two orders of magnitude. Therefore, the common practice of neglecting trapping number effect during polymer flooding might be misleading, particularly in carbonates that are characterized by a shallow CDC. Trapping number effect on oil recovery by polymer flooding depends on rock type and the targeted polymer viscosity, so the results might vary. The results indicate as well the effect of polymer flooding in improving both displacement and volumetric sweep efficiencies. The effect incorporated in this study is the elastic effect without considering polymer viscoelasticity, which might require further investigation. The study at the laboratory-scale is considered as a basis for field-scale predictions.
Reservoir Surveillance Through Fall off Test in a Mature Field with Waterflooding
Authors: Tello Cristhian , Guerrero Ximena , Mora Gisela , Becerra Jerson , Taborda Tatiana , Escarraga Cristian , Parra Marly 
Published: July 2020

Abstract
This paper describes the successful case study of a new approach to a Fall Off Test (FOT) for reservoir characterization and pressure surveillance in a mature oil field with waterflooding. The main objectives are to evaluate fundamental reservoir properties, to study uncertainties attributed to well-to-well communications, and to validate the presence of potential fractures.
The first step was the evaluation of current waterflooding performance at the sand layer level using injectivity behavior and petrophysical information, prioritizing high remaining oil reserves. Also, well candidates were screened against wellbore integrity and operational execution. Once the technology was ready for deployment, a customized log acquisition, and reservoir surveillance program was designed for slickline operation to acquire fall-off test data in every mandrel properly. Finally, the interpretation was made in specialized software, which served as input to update analytical models and improve reservoir understanding.
The proposed technology offers an innovative way to improve reservoir management through a cost-effective and credible application for pressure surveillance, taking advantage of selective-string capabilities for zonal evaluation. In addition, the methodology can be applied in oilfields where permanent downhole sensors are installed in intelligent completions for water injection purposes.
An Integrated New Exploitation Strategy in Bloque 61, from Modeling to Full-Field Implementation
Authors: Piñeiros Silvia , Mendoza María Alejandra , Cevallos Gonzalo , Molina Edison , Azancot Annalyn , Bermeo Pablo 
Published: July 2020

Abstract
A new Integrated Exploitation strategy to boost production and incorporate reserves at the Ecuadorian Bloque 61 was put on the table to radically change the production strategy from primary to secondary recovery in only two years timeframe. This was accomplished by drilling appraisal, development and infill wells in conjunction with peripherical and pattern waterflooding.
The project departed from reservoir characterization and modeling to identify the potential targets for waterflooding. The identified opportunities were assessed and ranked. Consequently, several pilots were implemented as a proof of concept.
Once the waterflooding pilots were in place, the complexity of the reservoir was evaluated. To account for the subsurface uncertainties, a probabilistic approach was followed to do the economical evaluation and risk management for the expansion.
Novel facilities configuration, implementation of new completion design and production enhacement techniques, along with a robust surveillance plan played a key role for the rapid implementation of a new exploitation strategy.
Positive reservoir pressure response and incremental production were observed within one to three months right after injection started in the pilots. This behavior was similar for the other fields where waterflooding was expanded. As such, new wells drilled and well reactivations in areas influenced by waterflooding has proven to have a threefold increase in expected initial productivity, therefore, the increase of reservoir pressure opened new development opportunities in Block 61 in former depleted reservoirs.
The implementation of a new exploitation philosophy focused in secondary recovery, increased recovery factor in about 10%, the contribution from waterflooding is about 30% of the total oil production. Additionally, 50% of the volume to be developed, corresponds to activity to be completed in Waterflooding areas.
This waterflooding strategy represents a shift in the exploitation paradigm in the Ecuadorian E&P industry, by going beyond the pilot execution through proper risk and uncertainty management as a path to full-field implementation. To fast-track this deployment of the water injection, a closed loop system was implemented between the water source and the injector to reduce facilities costs up to 80% as no treatment is required for the injected water.
Optimization of Casing Design for Wells Drilled in Llanos Region in Colombia. A Technical Analysis of the Problematic and the Adopted Solutions.
Authors: Romero Carolina , Alvarez Jorge 
Published: July 2020

Abstract
The objective of this paper is to present a timeline of the different well designs used in Llanos 34 Block that led to obtain the slimmest well design possible, indicate the challenges experienced with every well design, and the casing design recommendations and developments to mitigate these challenges.
Within this paper, we present the challenges that led to a new well architecture and the results in the field. The paper includes the detailed engineering analysis for the new architecture, including casing design, and torque and drag analyses. Additionally the paper compares the results in the field with the engineering analysis to validate the inputs and models. Finally, the paper includes a summary of the cost reductions of the new architecture and the lessons learned related to the models, operations and casing connection technology.
Different alternatives of well design were analyzed for the wells to be drilled in Llanos 34 Block, depending on the horizontal displacement required. Initially, a three section well was design with horizontal displacement of 4,000 ft or higher, considering a 9 5/8" production casing with a high collapse grade; and another option with a two sections well design when the vertical section was below 4,000 ft, with a 7" production casing. This alternative presented the opportunity to optimize costs and drilling time. The engineering analysis for the new architecture presented a challenge for running 7" casing in a longer open hole section; with very high values of torque expected. The casing connection manufacturer worked to improve the design of the connection to reach the required torque. In June 2016, the operator drilled the first well with the new architecture obtaining very good results, reducing cost and improving service performance. As a result, the new architecture became the standard with 46 drilled wells from June 2016 to June 2019. This paper includes the engineering analysis of new highly deviated wells and the casing connection technology developed for these new requirements.
The experience obtained by the optimization of the well design in Llanos 34 Block and the technical challenges faced by the production casing, can provide to different operators ways to optimize their well designs.
Synthetic Base Drilling Fluid Applications Under Extreme Pressure and Temperature Conditions in Gulf of Mexico
Authors: Hernandez Monserrat , Quissak Felipe , Córdova Monica , Torres Jorge 
Published: July 2020

Abstract
The design of an invert emulsion fluid that can hold up more than 24,000 psi and 435°F is a complicated and exhausting process. The challenges presented in the design of an UHPHT drilling fluid formulation are the base oil selection and the complete drilling fluid formulation. Flash point measurement of base oil before and after heat ageing to ensure that the base fluid were stable and the overall stability of the mud system need to be assured (rheology, gelation, fluid loss and weight material suspension) after both dynamic and static ageing for at least 96 hours at anticipated maximum BHST.
Laboratory pilot testing allows us to find a chemical balance where the rheology profile and mud properties fulfill the UHPHT project requirements. The laboratory testing protocol validation is the most important factor to prevent different issues during the drilling phase. This testing will be a contributor factor to conclude a well successfully.
Another phase of the design that we need to consider is an exact dynamic temperature modelling because a more precise Bottom Hole Temperature profile helps optimize the drilling process to increase the possibility of borehole stability.
A New Approach to Design Completion Fluids Including Hydrate Inhibition in Deep Water
Authors: Espinoza Juan Carlos 
Published: July 2020

Abstract
In the completions of deep-water wells with the presence of gas, it may be necessary to use gas hydrate inhibitors, in these cases the design of the completion fluid usually focuses on determining the concentration of hydrate inhibitor and meeting the criteria of maximum pressure and minimum crystallization temperature of the brines. The effect of the hydrate inhibitor on the PVT behavior of the mixture is usually ignored, the changes in the compressibility of the mixture (brine - hydrate inhibitor) may be different from that of the brine without a hydrate inhibitor, and could place the pressure hydrostatic outside the mud window geopressure, compromising the stability of the well.
To solve the problem that represents the design of the completion fluid for wells in deep water environments, in this work a methodology of design of the completion fluid is proposed that integrates compliance with the requirements of hydrate inhibition, crystallization, and stability hydraulics. The methodology guides the design of the completion fluid, until it meets all the requirements of the well. The proposed methodology addresses deep-water environments, however, it can be applied to HPHT wells or in all cases where PVT changes occur in completion fluids.
Design of a Computational Tool in Python for the Calculation of the Optimal Potential in the Huyapari Field - Petropiar
Authors: Acosta Rommina 
Published: July 2020

Abstract
The current demand for fossil fuels will promote the search for techniques to increase hydrocarbon production, so methods are needed to accelerate the development of this resource. The use of computer tools in the oil industry is indispensable today; we use increasingly powerful algorithms that perform extremely complex analyzes, which enable us to obtain solutions to previously affected problems pending in the industry. Most of the time the lack of parameters forces engineers to limit the study of a well, making restrictions and predictions not so accurate, especially regarding production; Based on this, the main objective is the development of a computational tool that allows to calculate the production potential of the wells drilled in the Huyapari field, which will use the python programming language, encoded from such a way to perform the calculations under the statistical methods of the analogous wells, the Joshi equation and nodal analysis. This tool is divided into two phases: the first is the calculation of the potential for pre-drilling and post-drilling of wells; the second phase is the adjustment of the potential that is carried out by means of the individual nodal analysis of each well taking into account the current reservoir pressure and the immersion limit of the pump.
Hybrid Nanomaterials for Enhanced Oil Recovery: New Alternatives for Polymer Thermal Degradation
Authors: Ruiz-Cañas María Carolina , Manrique Eduardo , Romero Arnold , Quintero Henderson 
Published: July 2020

Abstract
One of the alternatives currently emerging as a solution to the problems presented by the HPAM in high temperature reservoirs is the use of nanotechnology as a tool to improve and potentiate the properties of the polymer. Nanoparticles have been used to improve the stability and viscosity of HPAM solutions and their properties could be an important tool to improve the thermal resistance of polymers. The scope of this work is the evaluation of new hybrid nanomaterial based on HPAM and nanoparticles of silica dioxide.
The new prospective hybrid nanomaterials for oil and gas including Enhanced Oil Recovery (EOR) applications in were characterized including its thermal properties with applied advanced techniques such as Scanning Electron Microscopy (SEM - EDS), X-Ray Photoelectron Spectroscopy (XPS) and Thermogravimetric Analysis (TGA). These techniques contributed to demonstrate the formation of a covalent bond between the nanoparticle and the HPAM polymer, which allows having an inorganic - organic interaction that, according to its thermal properties, has a great potential in polymer flooding, among other applications.
The results obtained with these techniques were compared with the synthesis precursors, which shows the morphological, structural and property changes of the new nanomaterial with respect to the synthetic polymer. The elemental analysis carried out by EDS demonstrate the presence of C, N, O and Si in the structure of the new nanomaterial based on silica nanoparticles.
The high-resolution spectra obtained by the XPS technique show the functional groups corresponding to the covalent bond between the polymer and the nanoparticle, which provides a greater thermal resistance to the nanomaterial with respect to the conventional polymer. This thermal resistance is determined with the thermogravimetric analysis, in which the polymeric precursor and the new nanohybrid are subjected to a high resolution temperature ramp with a change of 10ºC / min from 25ºC to 700ºC. The results present a competitive advantage to the commercial polymer throughout the evaluation range, which will allow increasing the application ranges of the HPAM polymers and potentially inducing an increase in the recovery of oil.
Surveillance System for Dehydration and Desalting Process Optimization by Chemical Mitigation for a Marine Terminal in Mexico
Authors: Claib Meinhardt Amin Adolfo , Guan Hua , Lopez Cisneros Luis Fernando , Perez De La Cruz Marco Antonio , Lorenzana Alberto , Guerra Carvallo Claver Hugo , Ruiz Roque Sergio Ivan , Ramirez Olarte Hector Eric , Balderas Perez Harvey David 
Published: July 2020

Abstract
Oil quality management is an ongoing challenge, and there are costly financial implications when the product quality falls below the required specifications for trading. Furthermore, it has been reported that upsets in the dehydration and desalting (D&D) process leading to off-specification oil quality are commonly experienced following well interventions (stimulations and cleanouts), particularly when dealing with heavy oil.
Detailed research of problems at one D&D facility was conducted, starting with the analysis of existing field data (mainly from well stimulation and cleanout jobs) and recommending and processing laboratory tests to identify the root causes. A chemical mitigation strategy was developed with the implementation of key performance indicators (KPI) and workflows in a production operations software platform, which includes a surveillance and smart alert system that displays KPIs on dashboards for chemical management, mapping for forecasting scenarios of well jobs, time to arrive to the D&D facility, and chemical injection forecasting. The production operations platform is used for input data and generating dashboards including data from SCADA and dynamic multiphase flow simulation online systems to obtain and build the gathering network locations for all jobs and the lapsed time to arrive at the D&D process, making back allocations to gathering stations.
About 30% of stimulation and cleanout jobs have affected the D&D process due to increased volume of suspended solids in the system; these act as natural emulsifiers at the water-oil interface, contributing to emulsion stabilization. When the emulsion is highly stable, the applied chemical treatment becomes ineffective downstream; the D&D process is therefore unable to effectively remove water and salt from oil. The irregularity of the demulsifier injection also adversely affects the efficiency of the process.
The completion of this work provided a clear understanding of the root causes and insights into KPI behavior. The integrated solution enabled real-time monitoring and optimization of the chemical mitigation through better data usage and interpretation using the production operations platform combined with the multiphase flow simulator online system. This enabled the operator to perform timely monitoring and to proactively take actions to reduce the impacts on heavy oil quality.