bluuebunny/crossref_metadata_2025_split huggingface dataset:
Low Salinity Water Injection Optimization in the Namorado Field Using Compositional Simulation and Artificial Intelligence
Authors: Mercado Sierra Diana , Alvarez Rojas Argenis , Salazar Araque Victor 
Published: July 2020

Abstract
This work aims to optimize the development plan involving Low Salinity Water Injection – LSWI for the Namorado Field (located in the Campos basin in Brazil). Multiple mechanisms have been proposed in the literature to represent LSWI, mechanisms that we are going to discuss in this paper. Additionally, it will be studied the impact to evaluate multiple geostatistical realizations at the same time with multiple development scenarios (Robust Optimization) to select the optimal Net Present Value (NPV) of the project considering the reservoir uncertainties.
This methodology combines compositional simulation and a mathematical optimization tool that uses artificial intelligence to maximize the NPV of the project under evaluation. Considering that LSWI alters the initial chemical equilibrium in the reservoir and induces changes in the system, a geochemical model is included with aqueous reactions, dissolution / precipitation mineral reaction and ion exchange. The optimization project was carried out in three stages, first a multiple assisted history match, followed by a probabilistic forecast and finally, a robust optimization.
As a result, an optimum operational strategy of LSWI was obtained in which the impact of changing the type, location and number of producer and injector wells as well as the volume of injected water (High Salinity Water Injection (HSWI) vs. LSWI) are considered. On average, the optimal scenario for LSWI obtained a recovery factor of 41%, compared to 34% if only conventional water is injected. The selection and optimization of the recovery strategy considered multiple geological realizations and multiple history matched models in the field development plan, this considers the uncertainty associated with the porosity, permeability and net to gross distribution, with the objective of increasing the accuracy and reliability of the results obtained for the recovery factor and the NPV. For the optimal LSWI case and considering five different selected geological scenarios (P10 to P90), the recovery factor obtained was between 37.89% (P10) and 42.21% (P90) and the project NPV between 807 MMUSD (P10) and 3315 MMUSD (P90).
This adapted methodology allowed to obtain the optimal development plan considering the uncertainty associated in the reservoir, using multiple geostatistical realizations and multiple history matched models at the same time (usually just one history match is considered).
Coupled Flow-Geomechanics Simulation of Fracturing-to-Production in Unconventional Reservoirs
Authors: Rodriguez Adolfo A. , Monteagudo Jorge E. , Nieto Nathalie E. , Primera Alejandro 
Published: July 2020

Abstract
We have developed a computational platform that allows the simulation of coupled flow-geomechanics-fracturing in a seamless manner. This allows consistent simulation of water flow back, proppant placement and production. The simulation process starts with the hydraulic fracturing process which is implemented by solving the fully coupled flow-geomechanics problem. Next, a critical stress intensity factor is computed which rules the fracture propagation process. For the results presented in this paper, we consider the simultaneous propagation of all the fractures belonging to a single stage. After the fractures have been successfully created, injection is stopped for a given number of days after which oil production starts. We showed a set of synthetic results that illustrate the stress and pressure changes that occur during fracturing and production of unconventional wells.
Laplace Domain Pressure Behavior Solution for Multilayered Composite Reservoirs
Authors: L. F. Bittencourt Neto Jessica , Vieira Bela Renan , Pesco Sinesio , Barreto Abelardo 
Published: July 2020

Abstract
This work proposes an analytical model to compute the pressure response for radially heterogeneous multilayer reservoirs. The analytical model proposed in this work was developed based on equations that model pressure behavior during multilayer conventional production tests. A system of linear equations in Laplace domain is built, representing all differential equations, boundary and coupling conditions. The solution of this linear system in Laplace domain is inverted to real domain through Stehfest’s Algorithm. Layer properties such as permeability, oil viscosity, and porosity may be different for each layer. The computed pressure may be used to determine the main properties of an equivalent single-layered radial composite system that responds in the same manner as the heterogeneous one.
A Novel Solid Lubricant Uses the Principles of Tribology to Reduce the Coefficient of Friction COF in Oil- Based Muds OBM for Extended Reach Drilling Applications
Authors: Ramirez Mario A , Pritchard Ryan 
Published: July 2020

Abstract
Extended reach horizontal wells face significant challenges in drilling longer laterals with oil-base mud (OBM). A novel solid-state lubricant was developed to close the gap in limitations of liquid lubricants and OBM with respect to lubricity in long extended lateral sections. The novel solid lubricant reduces the surface contact area between the asperities (deformations) by rolling and provides a chemically bonded film on the contact areas to reduce the amount of shear stress between the surfaces.
There is limited understanding of the complex mechanisms affecting the coefficient of friction (COF). The principles of Tribology (the science of friction, lubrication and wear) were used to develop the solid-state lubricant. The Stribeck Curve describes the regimes while using a lubricant, including boundaries mixing elasto-hydrodynamic and hydrodynamic lubrication. Liquid lubricants are limited at controlling boundary conditions where the COF is ruled by asperities in contact between the surfaces. The novel solid-state lubricant works on the asperities of both the wellbore and bit/BHA. In addition, the COF is improved in the mixed and elasto-hydrodynamic lubrication regimes.
Several oil-based mud field samples were tested for lubricity using different methods including the EP Lubricity Meter and Dynamic Lubricity Evaluation Monitor (LEM). The novel solid-state lubricant was also tested using a Tribometer to produce a continuous Stribeck curve that enables evaluation of the lubricant in the entire lubricity regime. The results of the COF using EP Lubricity Meter were transformed calculating the Stribeck number to build the curve. The potential benefits of the solid lubricant were discussed using a model developed by the Stick Slip vibrations with Stribeck curves. A reduction of COF in the boundary lubrication region occurs when the asperities of the wellbore and the bit/BHA are in contact. This is explained by the adsorption and absorption of the novel solid-state lubricant onto the asperities, providing a smooth surface. The novel solid-state lubricant has a wide particle distribution (PSD) to cover different size and height of asperities. The Stribeck curves of the novel solid-state lubricant show that the lubricant can reduce COF in the boundary lubrication region where friction forces are highest, compared with a base fluid and other liquid lubricants.
Real Time Measurement of Resistivity at the Bit Allows Optimal Casing Point in JSO Sands
Authors: Cruz Nancy , Luna Mabel , Reyes Carlos 
Published: July 2020

Abstract
In Mexico, the development fields of the northeastern marine region have complex geological structures, which have formations with thicknesses that limit well directional operations, especially those related to the construction of high-angle curves in the reservoir.
Derived from the current challenges and demands in well drilling, the requirement of a greater area of ​​contact in the reservoir to increase the oil production, causing the drilling of wells in a high angle and forcing the use of various technologies to minimize drilling risks, turning them into methods for optimization.
This technical document shows the application of resistivity technology close to the bit, providing added value to geological control and monitoring during drilling, allowing the collection of information as a key point for critical casing points.
When drilling of a horizontal well, the problem of performing high angle curves in formations with risk of generating non-productive times is addressed, as well as the reduced thickness in certain areas of the reservoir are limiting for the construction of the horizontal section. Performing the correct casing point at the top of the reservoir allows the anhydrite zone to be isolated, which represents a potential risk during drilling.
As a result of real-time monitoring of the resistivity at the bit and the interpretation of structural geological information from correlation wells, minimization of the uncertainty to casing point in the desired formation was achieved, providing a wide vertical thickness margin, to achieve planned trajectory and position the well within the desired rock unit.
Benchmarking Drilling Performance of PDC and Hybrid Bits in an Offshore Interbedded Environment, Based on Bit Design and Features
Authors: Serrano Ralph Adeleke , Roy Chowdhury Ashabikash , Schoen William , Samuel Ronald 
Published: July 2020

Abstract
Interbedded formations are challenging to drill due to its potential to trigger torsional instability issues while drilling at low depth-of-cut (DOC), which could damage the bit due to impact and result in low penetration rate or an undesired trip. Wells drilled in the Guyana-Suriname Basin face a similar challenge as the wells penetrate interbedded shale and carbonates, causing conventional polycrystalline diamond compact (PDC) bits to lose their cutting efficiency due to impact damage while drilling the hard, interbedded formation.
Using a detailed bench-marking methodology, offset drilling data was analyzed and the results were utilized to optimize bit design to meet these challenges. Mechanical specific energy (MSE), which quantifies drilling efficiency, indicates formation changes and signals the advanced dull condition or damage. When coupled with dull bit forensics, MSE provides insight for iterative bit design optimization to mitigate drilling challenges.
The outcome of a detailed benchmarking process led to the selection and deployment of a 12¼-in. hybrid bit to drill directionally through interbedded formation, which significantly improved drilling performance and bit durability. The hybrid bit combined PDC and tungsten carbide insert (TCI) rolling cutting elements and delivered balanced aggressiveness to improve torisonal stability. Post-well analysis showed rolling DOC control offered by the hybrid bit delivered higher penetration rate. The comparison of the drilling mechanics of the hybrid versus PDC highlighted limited drilling efficiency of PDC bits in interbedded formation. The hybrid bit drilled 54% more carbonates than the best PDC offset run. Drilling dynamics data also highlighted lower levels of vibrations with the hybrid bit. In addition, the hybrid dull condition was better than the PDC bits, suggesting improved durability compared to the previously-used PDC bits.
This paper demonstrates time and depth based surface and downhole drilling data, when supplemented with rock strength analysis using a suitable benchmarking process, can provide insight about drilling mechanics. When matched with an application specific bit, it leads to sustained drilling performance improvement.
Non-Intrusive Parametric Model Order Reduction with Error Correction Modeling for Changing Well Locations Using a Machine Learning Framework
Authors: Zalavadia Hardikkumar , Gildin Eduardo 
Published: July 2020

Abstract
The objective of this paper is to develop a non-intrusive Parametric Model Order Reduction (PMOR) methodology for the problem of changing well locations that can eventually be used for well placement optimization, to gain significant computational savings. In the past, model order reduction strategies developed for the case of changing infill well locations are limited to the scale of application, with majority of focus laid on development of MOR for changing controls of the wells for well control optimization. In this work, we propose a proper orthogonal decomposition (POD) based PMOR strategy that is non-intrusive to the simulator source code, as opposed to the convention of using POD as a simulator intrusive procedure, and hence extends its applicability to any commercial simulator. The non-intrusiveness of the proposed technique stems from formulating a novel Machine Learning (ML) based framework used with POD. The features of ML model (Random Forest used here) are designed such that they take into consideration the temporal evolution of the state solutions and thereby avoiding simulator access for time dependency of the solutions. The proposed PMOR method is global in the sense that a single reduced order model can be used for all the well locations of interest in the reservoir. We address a major challenge of explicit representation of the well location change as a parameter by introducing geometry-based features and flow diagnostics inspired physics-based features. An error correction model based on reduced model solutions is formulated later to correct for discrepancies in the state solutions at well gridblocks.
The proposed methodology is applied to a heterogeneous channelized reservoir using a section of SPE10 model, to analyze and validate the proposed idea. It was observed that the global PMOR could predict the overall trend in the pressure and saturation solutions at the well blocks but some bias was observed that resulted in discrepancies in prediction of quantities of interest (QoI) like oil production rates and water cut. Thus, the error correction model proposed using Artificial Neural Networks (ANN) that considers the physics based reduced model solutions as features, proved to reduce the error in QoI significantly. Speed-ups of about 50x-100x were observed for different cases considered when running the test scenarios. The proposed workflow for reduced order modeling is "non-intrusive" and hence can increase its applicability to any simulator used. Also, the method is formulated such that all the simulation time steps are independent and hence can make use of parallel resources very efficiently and also avoid stability issues that can result from error accumulation over timesteps.
Assessing Well Integrity During Its Life Cycle Due to Primary Cementing
Authors: Miura Kazuo , Anunciação Jaculli Marcelo , Pelaquim Mendes José Ricardo , da Mata Cristian Roberto , Colombo Danilo 
Published: July 2020

Abstract
Primary cementing during well drilling operations aims, among other objectives, to provide structural stability by transferring well loads to surface formations, as well as being a safety barrier between casing and formation in order to prevent undesirable flow from permeable zones along the formation. The present work discusses whether permeable zones should be cemented along with impermeable zones, as degradation of cement quality has been observed in permeable zones due to, for example, circulation losses.
According to API (2010), between 1960 and 1996, 6.5% of all primary barrier losses were related to problems with cementing. Thus, in this work we evaluate the quality of well primary cementing based on the hydraulic power developed during the cementing job, in order to discuss better cementing practices. In order to perform this analysis, data is collected from Santos basin in Brazil regarding cementing of production casings and liners in pre-salt wells, with 3 or 4 phases.
Results show data collected from the drilling and cementing projects for selected wells, such as cement and cementing properties (density, volume, flow rate), casing properties (depth of casing shoes, diameter, weight), cement logging (expected vs. measured cement height, adherence quality of casing-cement and cement-formation), and drilling history (related operational problems). This data is then used to calculate the hydraulic power developed and to compare the quality of primary cementing between a 3-phase well, in which cementing is performed simultaneously in the impermeable (cap rock) and permeable (reservoir) zones, and a 4-phase well, in which the impermeable and permeable zones are cemented separately. Comparison between different wells allows us to verify our concerns regarding the quality of primary cementing in permeable zones, and to attest the quality of primary cementing as a barrier during the well life cycle.
Usage of the developed hydraulic power to attest the quality of primary cementing based on field data is a novel approach as a quantitative methodology for assessing well integrity and safety, becoming a tool that aids decision-making during well design, such as in selecting the number of phases or choosing appropriate cementing procedures.
Combining Machine Learning with Traditional Reservoir Physics for Predictive Modeling and Optimization of a Large Mature Waterflood Project in the Gulf of San Jorge Basin in Argentina
Authors: Calad Carlos , Gutierrez Fernando , Pastor Paola , Sarma Pallav 
Published: July 2020

Abstract
A novel technology that combines the benefits of speed of data sciences with the predictivity capabilities of traditional simulation is being applied to model two blocks of a large waterflood project in the Gulf of San Jorge basin in southern Argentina. The tool is being used to provide a prescription of injection water redistribution that optimizes production and reserves development and reduces injection cost.
The technology used is called DataPhysics* and combines the robustness of reservoir physics with the speed of data sciences techniques. The process solves a limited number of unknowns in a continuous scale making it several orders of magnitude faster than traditional numeric simulation. The reservoir model is created from raw (uninterpreted) data and is updated continuously allowing for close loop reservoir optimization in real time. Long term predictivity is enabled by the fact that the tool honors the reservoir physics.
At the time of writing this paper the recommendations of the predictive model have been implemented in the pilot sector of the field and early positive results have been observed.
One of the Deepest Wells Drilled in Bolivia: High Pressure and Temperature in more than 9 Months of Drilling, No Casing Wear Detected
Authors: Mertens Russell , Garcia Jesus , Bertarelli Valcárcel Mario Alberto , Duran Camargo Romulo 
Published: July 2020

Abstract
Casing wear caused by rotating drill strings can lead to reduced well integrity or increased well maintenance. Furthermore, excessive casing wear can lead to remedial actions, expensive non-productive time, failed casing, or safety hazards. Mechanical casing wear is a function of drill pipe contact pressure, drill pipe revolutions, and wear factor. Casing wear can be an issue anywhere in the world, but this paper examines these challenges in a particular well in the Bolivia's sub-Andean region. The historically low rate of penetration (ROP) of 1.3m/hr caused nine months of drilling operations inside the production casing. As a result, the production casing was exposed to 11.3 million drill pipe rotations. The operator with extensive experience drilling wells in this region identified the critical importance to mitigate casing wear. The strategy was to implement the use of Non-Rotating Protectors (NRPs) after the production casing was set in the hole to drill the last two hole sections. While casing wear reached 13.2%, an analysis indicates the wear would have reached 80% had NRPs not been used.
Additional challenges were expected due to high temperature and pressure in the lower sections. By using tools suited for these extreme conditions, one of the deepest wells in Bolivia was successfully drilled.
Early Engagement Collaboration to Evaluate Business Opportunities in Crude Trading Industry
Authors: Torres Montiel Adelfo , Ramirez Lopez Christian Alan 
Published: July 2020

Abstract
The objective of this paper is to present a comprehensive methodology to perform an initial evaluation of market size and potential value of a new hydrocarbon's transportation and commercialization network in Mexico.
The methodology is based in an integrated multi-domain evaluation from geoscience and reservoir engineering to facilities design and economics; covering four main aspects: 1) Confirmation of reserves and estimated resources, 2)Generation of production forecasts, 3) Pipeline network design for two sales terminals and 4) design plot of sales terminals with processing facilities to handle expected production. The four aspects are supported by an economic evaluation with multiple tariff scenarios for varied break-even and profitability targets.
The initial confirmation of reserves and resources for more than 70 fields spanning greenfields and brownfields alongside with exploration areas yielded the basis for the analysis which was supported on statistical analysis of analogue fields combined with a geological interpretation of the target basins. Production forecasts from multiple scenarios grouped by region and nationwide confirmed expected production input into the newly proposed transportation network which was compared against forecast from some of the operators with a reasonable match. Pipeline network design for heavy and light crude with flow assurance considerations provided the pipelines diameters and length to consider for the economic case and the inlet pressure for two terminals. Finally, the design plot of the facilities required at the terminals allowed to size land and infrastructure requirements at a pre-Front End Engineering Design (FEED) level. The economics showed feasibility of the production input scenarios at different tariff for the trading company considering the initial investments required to build the new transportation and commercialization network.
A novel integrated engineering solution combining domain expertise with processing and facilities design covering reserves and resources confirmation for more than 70 fields, production forecasts for all fields and aggregated to regional level, general assessment on infrastructure required to build a new transportation network and finally the infrastructure pre-design for two processing and commercialization terminals.