bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Tool for Achieving the Base Production Potential
Authors: Zhdanov I. A. , Andzhukaev Ts. V. , Margarit A. S. , Pustovskikh A. A. 
Published: October 2017

Abstract
The achievement of the well potential in the majority of Russian oil companies is monitored on an advisory basis using low-integrated approaches and tools. These processes are not automated enough [1]. As a result, 80% of the labor is spent on performing routine operations: collecting and preparing input data for analysis. This leads to suboptimal and untimely decisions to manage the development of current assets, and consequently, to lost production, increased water cut, an increase in the time to achieve the estimated oil recovery factor (oil RF), and unproductive injection into induced fractures. Thus, the purpose of this paper is to develop a decision support tool for a reservoir engineer.
This paper describes the methods and functionality of the tool used to achieve the potential of the base production, which makes it possible to automatically, systematically and efficiently formulate recommendations for injection control, to select wells that are optimal for conversion to injection, to select candidates for treatment of the bottomhole zone, remedial cementing, well logging, and flow tests.
Building and Application of Integrated Model of a Large Sakhalin Offshore Oil and Gas Condensate Field
Authors: Kuzevanov M. A. , Skvortsov D. O. , Karmazin M. S. , Buchinskiy S. V. 
Published: October 2017

Abstract
Integrated modeling is a tool of managing a process of hydrocarbon production from an asset, which consists of downstream and upstream elements. Integrated model subsequently covers complex relationships between reservoirs, wells, pipelines and elements of subsurface infrastructure. In many ways, efficiency of oil and gas field development depends on these relationships [1]. For this reason, modeling of a hydrocarbon production process should embrace a whole chain (from upstream to downstream) and integrated modeling is best suited for this task [2]. The main purpose of this work was to evaluate the possibility of well operation condition optimization with account of subsurface infrastructure using integrated modeling tools.
The paper gives a review of a modern approach to modeling a large Sakhalin offshore oil and gas condensate field, the X Field. Oil producers have been drilled from the shore into oil rims of reservoirs with record-breaking horizontal offset in the oil and gas industry. Initial oil rates exceed 3000 ton/day. However, the field development is complicated at the moment, due to gas breakthrough from the gas cap which leads to a critical decline in well performance. An integrated model includes simulation models of two oil/gas reservoirs, well models, and a model of single gathering system. The paper briefly describes the approach to building and matching the integrated model.
After building and history matching of the integrated model, sensitivity of oil production to a change in well operation condition was analyzed. Also, mutual well influence on the gathering system level was evaluated. As a possible scenario for well operation condition improvement an intermittent well operation was considered. The results of model runs demonstrate that a change in well operation conditions won't positively affect oil production in short period.
Integrated Modeling as an Instrument for Unique Gas Condensate Field Development Concept Choice
Authors: Gataullin T. I. , Poushev A. V. , Prokopenko A. V. , Sullagaev A. V. 
Published: October 2017

Abstract
One of the most important challenges of the current stage of the field development is selection of concept of infrastructure system development and solution of classical problem of optimization:
Minimization of capital expenditures for infrastructure development, Minimization of cost of production, treatment and intra-field transportation of the raw material to the LNG plant, Ensuring of high reliability of the entire infrastructure system for continuous flow of raw material to the LNG plant trains. Reaching of the field performance targets, namely: - Duration of the period of continuous gas production - Hydrocarbons recovery factors
Besides, in designing of the infrastructure system and accordingly, in selection of the solution, it is necessary to take into account the following factors representing complexity of the future industrial activity in general:
Geographical location of the field in the area with challenging climatic (arctic) conditions which calls for the necessity of maintaining of high level of self-sustainability in the field; Considerable differences in values of formation and accordingly, wellhead pressures of the production wells stock;
Taking an optimal decision in part of concept of infrastructure development in these challenging conditions is possible only on the basis of the complex integrated digital model "Well - Reservoir - Gathering network - Treatment system" allowing for correct evaluation of engineering parameters of field development with account for the effect of existing limitations related to reservoir, well design, downhole equipment, gathering system and production treatment.
Solving of this problem using the up-to-date modeling technologies accounting for mutual effect of all elements of the system on the basis of multi-disciplinary teams includes the following:
Generation of the integrated models "Reservoir - Wells - Gathering system - Treatment system - In-field transport system to the LNG Plant Inlet", Separation of individual types of process design calculations for analysis with consequent incorporation into the integrated model, Carrying out of multi-option calculations of engineering parameters of development and infrastructure, Assessment of the results of calculations of engineering parameters of options by specialists of the multi-disciplinary team, Economic assessment of costs of implementation of the studied options.
Using the above mentioned approach with involvement of the integrated field model, multi-option calculations of location and parameters of production treatment facilities and dynamic calculations of flow lines operation parameters for various scenarios of the LNG plant were performed.
Analysis of Geological and Hydrodynamic Uncertainties in the Design of Field Development Indicators
Authors: Kravtsov A. I. 
Published: October 2017

Abstract
For the most objective evaluation of deposits with low geological knowledge and obtaining the scope of the most likely development results, the use of uncertainty analysis tools is necessary. This type of analysis includes the maximum possible set of geological and hydrodynamic parameters that have a major impact on hydrocarbon production levels, where each of them has uncertainties that affect the final result to varying degrees. All these parameters are subjected to probabilistic estimation in terms of compliance with available information on well testing. To solve the problem of a large number of estimation options, the most optimal methods for creating model implementations and using proxy modeling are applied. The application of the developed algorithm allows to evaluate both the hydrodynamic and geological parameters of the model for the probabilistic distribution of hydrocarbon reserves by strata and the results of production in the field as a whole. The performed works allow to make detailed recommendations on the removal of the most critical uncertainties for the objects of study.
Hybrid Approach to Reservoir Modeling Based on Modern CPU and GPU Computational Platforms
Authors: Telishev Alexey , Bogachev Kirill , Shelkov Vasilii , Eydinov Dmitry , Tran Hau 
Published: October 2017

Abstract
For modern day reservoir simulators, it is essential to provide realistic physical description of reservoirs, fluids and hydrocarbon extraction technology and guarantee excellent performance and parallel scalability.
In the past, the advances in simulation performance were largely limited by memory throughput of CPU based computer systems. Recently, new generation of graphical processing units (GPU) became available for general purpose computing with the support of double precision floating point operations, necessary for dynamic reservoir simulations. The graphical cards currently available on the market have thousands of computational cores that can be efficiently utilized for simulations.
In this paper, for the first time we present results of running full physics reservoir simulator on CPU+GPU platform and discuss implications of this modern technology on the existing reservoir simulation workflows. We discuss challenges and developed solutions for running reservoir simulations using modern CPU+GPU hardware architecture and propose a methodology to distribute the workload between various parts efficiently. The approach is tested on several data sets on various computational platforms, such as personal computers and clusters with and without GPU's involved.
The technology proposed in this paper demonstrates multifold speed up for models with substantial number of active grid blocks. The speed up due to GPU utilization can in some cases reach as high as 3-4 times compared to the traditional GPU-based approach. Considering the recent progress in the GPU development, this factor is expected to grow in the near future, and the hybrid CPU+GPU based approach allows to utilize the exciting potential of the hardware evolution. The results, advances and potential bottlenecks combined with detailed analysis of the performance and the ‘value for money’ of the modern hardware solutions are discussed.
Reactive Flow Modeling at Pore Scale
Authors: Beletskaya A. , Ivanov E. , Stukan M. , Safonov S. , Dinariev O. 
Published: October 2017

Abstract
Design of acidizing job involves application of reactive flow modeling. Most of the existing research and commercial codes for reactive transport modeling are based on Darcy-scale continuum representation of porous media. Such kind of simulations requires application of tuning coefficients, which, if not chosen properly, lead to inappropriate design of acidizing job. To overcome this issue, we have proposed direct reactive flow modeling approach at a pore scale using exact pore geometry.
The approach developed in this work is based on the combination of principles of chemical kinetics/thermodynamics and density functional theory applied for hydrodynamics (DFH). Chemical reactions are introduced to hydrodynamic simulation within the framework of partial local equilibrium assumption.
In the current study, it is demonstrated that developed approach adequately describes dissolution of porous dolomite rock by solution of hydrochloric acid. Simulations have been performed using 2D model of dolomite granule, 2D model of porous structure and 3D model of Silurian dolomite microstructure. Upon acid injection, the geometry of a rock is gradually changing in the area of acid penetration. As a result of modeling of dissolution of dolomite non-porous granule by solution of hydrochloric acid it is shown that the rate of dolomite dissolution depends on the rate of fluid injection. The average rate of dissolution is increased from 0.07 to 0.23 kmol/(m3·s) with the increase of Péclet number from 0.28 to 46. Similar correlations for porous rock with exact geometry can be utilized for corrections of the reaction rate constants which are used in Darcy scale simulations. Developed approach allows to perform modeling of dissolution reactions at pore scale and paves the way for increasing the consistency between the models used in reactive flow modeling and pore structure features of real rocks which will lead to improvements in acidizing job design.
Modeling Gas Condensate Reservoir Productivity via Industrial Software Solutions in Consideration of Trapped Phases and Closed Pores
Authors: Mikhailov N. N. , Voronich I. V. , Shelepanov S. S. 
Published: October 2017

Abstract
The aim of this work is to study the effect of the capillary trapping of phases in gas-condensate formations on the pattern of fluid filtration and, consequently, the productivity of gas condensate wells. The article proposes a method for increasing the accuracy of filtration modeling in gas condensate wells by including the effect of the capillary trapping in the filtration model.
In this paper, the Forchheimer's equation was used as the filtration law, which is most often used in the modeling of gas and gas condensate reservoir, since it describes the filtration with high-pressure gradients and high velocities quite accurately. The cases were simulated with various nonlinearity coefficients in the form of empirical functions of porosity and permeability described in the literature. Additionally, the work took into account the effects of capillary trapping of phases, the effects of compressibility of the reservoir and the effects of mudding of the wellbore zone. The residual saturation of each phase was calculated by the empirical function of the capillary number.
A solver for open-source software OpenFOAM, which is an integrated platform for computational fluid dynamics problems, was written and verified. The numerical model of this solver allows taking into account such effects as, for example, capillary trapping of phases, mudding of the near wellbore zone and other effects that impair the productivity of gas condensate wells. As a result of numerical calculations, a significant influence of the capillary trapping effect on the performance of gas condensate wells was revealed. The non-additivity of the discussed effect and other effects affecting filtration in the gas-condensate reservoir was shown. Accounting for one-side open pores in numerical simulation also made a significant contribution to the performance of gas condensate wells. The possibility of improving the accuracy of filtration modeling for industrial numerical calculations conducted via special software on supercomputers was shown.
A method for significantly improving the accuracy of fluid filtration modeling in gas-condensate reservoirs by including the effects of capillary trapping and one-side open pores into the numerical model is proposed. Such corrections of the numerical model does not lead to its significant complication and the speed of the computation increases slightly. Thus, the proposed method can be widely used for numerical calculations in the oil and gas industry.
Special Features of Geological Modeling of Shelf Sediments by the Example of East-Urengoy and North-Esetinsk Fields
Authors: Natchuk N. , Uraev O. 
Published: October 2017

Abstract
The work objective of research is improving the quality of the reservoir modeling of the shelf deposits in the Neocomian clinoform complex by means of identification the peculiarities of geologic structure of the layers, and using of them for create the geological models oil and gas reservoirs. The subject of research is BU16-18 layers in East-Urengoy and North-Esetinsk field. The main peculiarities of BU layers are lenticular body, the vertical and the lateral anisotropy of reservoir properties in the reservoir volume, the presence of transition water-oil zone in consequence of layer`s heterogeneous.
For identification and reservoir modeling of the peculiarities of geologic structure the shelf`s genesis layers used the results of seismic attribute analysis, fractional and mineral analysis of the rocks, conceptional model analysis about accumulation shelf sediments.
The result of the research are detecting all the peculiarities of geologic structure the shelf`s genesis layers such as lenticular body, the anisotropy of reservoir properties, the presence of transition water-oil zone. All peculiarities was introduced for create the geological models: structural framework building, expansion of the reservoir properties in the interwell space, saturation modeling taking into account transition water-oil zone parameters.
An Application of Proxy-Modeling Framework for Numerical PVT-Models Matching on Laboratory Measured Data
Authors: Tigran Ambarian , Dmitriy Olenchikov 
Published: October 2017

Abstract
The paper presents a new automated method of matching the equation of state (EOS) of multicomponent system to the laboratory measured data. The method is based on the idea of using a statistical estimator, which allows you to replace the entire space of possible PVT-models that correspond to different parameter values by a simplified, piecewise-polynomial proxy-model. During the application of the method, the proxy model is refined based on the results of intermediate calculations and a global search for the optimal solution is perfomed.
The new approach avoids the drawbacks of the traditional approach using the linear regression or gradient descent methods. The reason is that in highly non-linear problem traditional methods often finds only a local minimum and does not allow us to obtain a solution with an acceptable degree of accuracy. The proposed method allows to effectively adjust the PVT-model to actual data, and mostly times, with higher accuracy than the traditional method.
The application of this method to adjust the equation of state for laboratory measured data is shown by the example of one of the gas condensate field sample. This allowed to reduce the PVT-model error more than 5 times in comparison with the result of using linear regression.
Construction of a 3D Geomechanical Model for Development of a Shale Gas Reservoir in Sichuan Basin
Authors: Xie Jun , Qiu Kaibin , Zhong Bing , Pan Yuanwei , Shi Xuewen , Wang Lizhi 
Published: October 2017

Abstract
Currently, there is large-scale shale gas exploration and development in the Sichuan basin, western China. Due to high tectonic stress and presence of fracture systems at various scales in the lower Silurian Longmaxi reservoir formation, hydraulic fracturing in shale gas reservoirs in the Sichuan basin has encountered many difficulties, such as difficulty in placing sufficient proppant, poor production performance for some wells, and ambiguity as to the factors controlling production of the reservoir. It has been recognized that lack of geomechanical understanding of the shale gas reservoirs places a major obstacle to effectively addressing these difficulties.
A 3D full field geomechanics model was constructed for Changning shale gas reservoir in Sichuan basin through integrating seismic, geological structure, log, and core data by following a newly formulated integrated workflow. The 3D geomechanical model includes 3D anisotropic mechanical properties, 3D pore pressure, and the 3D in-situ stress field. Through leveraging measurements from an advanced sonic tool and core data, the anisotropy of the formation was captured at wellbores and propagated to 3D space guided by prestack seismic inversion data. 3D pore pressure prediction was conducted using seismic data and calibrated against pressure measurements, mud logging data, and flowback data. A discrete fracture network model, which represents multiscale natural fracture systems, was integrated into the 3D geomechanical model during stress modeling to reflect the disturbance on the in-situ stress field by the presence of the natural fracture systems.
The 3D pore pressure model was used to calculate more-reliable estimates of gas in place in the shale gas reservoir, and the geomechanical model was used to reveal the root cause of difficulties of proppant placement in this tectonically active and unevenly fractured shale gas reservoir.
The paper presents the highlights and innovations in constructing the 3D geomechanical model for the shale gas reservoir and explains how the 3D geomechanical model is used to understand the root cause of poor proppant placement encountered during hydraulic fracturing and events such as mud losses during drilling. Hence, the modeling provides a critical opportunity to improve reservoir stimulation in the shale gas reservoir.
Application of CRM for Production and Remaining Oil Reserves Reservoir Allocation In Mature West Siberian Waterflood Field
Authors: Gladkov A. , Sakhibgareev R. , Salimov D. , Skiba A. , Drozdov O. 
Published: October 2017

Abstract
A Capacity-Resistance Model was matched with production and injection data. Oil and water production splits and remaining reserves were calculated per reservoir unit. The results were validated with history matched streamline and conventional simulation model.
A Capacity-Resistance Model is based on material balance and signal processing of resistor-capacitor circuits where each circuit is represented by injector-producer pair per reservoir. The calibrated model is then combined with fractional flow model fit that is used to forecast water cut. CRM is based on injection and production data and injection splits. Based on this case study an engineer would have access to equations and methods that describe CRM predictive model and comparison with simulation models.
The relative simplicity of CRM model allows to use all available production and injection data in mature West-Siberian waterflood assets with large number of wells and to save time for decision-making on injection redistribution, infill wells, conformance treatment. CRM can be applied before simulation model is built and later the CRM results can be used in history match.
In this paper, we would like to analyze connectivity factors fij of CRM model and see how well the model matches the history.
Perspective Technologies of Reservoir Stimulation, Developed in RUE Production Association Belorusneft
Authors: Lymar I. , Serebrennikov A. 
Published: October 2017

Abstract
In the article we present the results of laboratory and pilot-field tests of advanced technologies of reservoir stimulation aimed at intensifying and increasing oil recovery (EOR) in the conditions of the deposits of the Republic of Belarus at a late stage of development (mature field).
We describe the approaches to the planning and implementation of scientific research studies aimed at solving specific problems.
The results of laboratory and experimental-field tests of such technologies are presented: –acid treatment (AT) using a self-deflecting acid system based on a solution of hydrochloric acid and a composition of viscoelastic surfactants;–acid treatment with nitrogenous acid formulations;–foam thermo-acid treatment;–stimulation of low permeable carbonate reservoirs-collectors by acid-proppant fracturing;–hydro monitor wash out of rocks;–physical-chemical methods of EOR, including wide-scale reservoir stimulation using a system of producing abandoned wells.