bluuebunny/crossref_metadata_2025_split huggingface dataset:
Complex Approach to Creation and Maintenance of Integrated Asset Models and Implementation of Digital Data Management Platform
Authors: Markov Pavel Vladimirovich , Gorshkov Alexey Vladimirovich , Shadrin Sergey Vladimirovich 
Published: October 2021

Abstract
The paper presents a complex approach based on the experience of the authors of this article for creating and maintaining integrated asset models (IAM) and implementing a digital data management platform. Problems of using IAM for the operational management of field development and production are that the data is not accurate, the measurements are spaced in time, and there is not enough data to understand the physical phenomena taking place. The complex approach is that to provide integrated asset models with high-quality data, it is necessary to build new processes, create new specialties and competencies, the key success factor is the combination of the experience of Customer (oil company), Internal oil-related service of Customer (geological and geophysical research), External contractor of oil-related service (the combination of experience in geological and geophysical research, experience in integrated asset modeling and operational support for field development using integrated asset modeling tools and digitalization of data management). The best way to implement the approach of creating joint Integrated Team of External and Internal oilfield service Contractors in the form of Complex Service Engineering Center, the task for which which was the organization of a cyber-physical system for collecting field data, verifying data, identifying problem areas in data, defining approaches to eliminating problem areas using tools of automation tools for working with data, the flexible management of well testing and survey programs, the operational formation of well testing and survey design for non-standard situations. Particular attention in this complex approach is paid to working with initial field data, this article provides a general scheme for verifying the various parameters of well operation and an example of its use for flow rates, as well as examples of the quality analysis of reservoir pressures based on the use of a two-dimensional one-phase proxy reservoir model and the quality analysis of GOR for a well. Based on the developed complex approach, the paper provides examples of strategic and operational problems for a field - the assessment of optimal production for a field and the assessment of oil shortfalls for a well, respectively.
New method for Handling of Infrastructural Constraints for Integrated Modeling in Steady Case
Authors: Olenchikov Dmitry Moiseevich 
Published: October 2021

Abstract
Recently, more and more reservoir flow models are being extended to integrated ones to consider the influence of the surface network on the field development. A serious numerical problem is the handling of constraints in the form of inequalities. It is especially difficult in combination with optimization and automatic control of well and surface equipment. Traditional numerical methods solve the problem iteratively, choosing the operation modes for network elements. Sometimes solution may violate constraints or not be an optimal. The paper proposes a new flexible and relatively efficient method that allows to reliably handle constraints. The idea is to work with entire set of all possible operation modes according to constraints and control capabilities. Let's call this set an operation modes domain (OMD). The problem is solved in two stages. On the first stage (direct course) the OMD are calculated for all network elements from wells to terminal. Constraints are handled by narrowing the OMD. On the second stage (backward course) the optimal solution is chosen from OMD.
Influence of Rock Plastic Behavior on the Wellbore Stability
Authors: Grishko Elena , Garavand Aboozar , Cheremisin Alexey 
Published: October 2021

Abstract
Currently, the standard approach to building a geomechanical model for analyzing wellbore stability involves taking into account only elastic deformations. This approach has shown its inconsistency in the design and drilling of wells passing through rocks with pronounced plastic properties. Such rocks are characterized by the fact that when the loads acting on them change, they demonstrate not only elastic, but also plastic (irreversible) deformations. Plastic deformations have an additional impact on the distribution of stresses in the rock of the near-wellbore zone on a qualitative and quantitative level. Since plastic deformations are not taken into account in the standard approach, in this case the results of the wellbore stability analysis are based on incorrectly calculated stresses acting in the rock. As a result, it can lead to misinterpretation of the model for analysis, suboptimal choice of trajectory, incorrect calculation of safe mud window and an incorrectly selected set of measures to reduce the risks of instability.
The aim of this work is to demonstrate the advantages of the developed 3D elasto-plastic program for calculating the wellbore stability in comparison with the standard elastic method used in petroleum geomechanics. The central core of the work is the process of initialization of the elasto-plastic model according to the data of core tests and the subsequent validation of experimental and numerical loading curves.
The developed 3D program is based on a modified Drucker-Prager model and implemented in a finite element formulation. 3D geomechanical model of wellbore stability allows describing deformation processes in the near-wellbore zone and includes the developed failure criteria.
The paper shows a special approach to the determination of the mud window based on well logging data and core tests by taking into account the plastic behavior of rocks. An important result of this study is the determination of the possibility of expanding the mud window when taking into account the plastic criterion of rock failure.
Usage of Geomechanically Consistent Fracture Model for Drilling Deviated Wells
Authors: Dubinya Nikita Vladislavovich , Tikhotskiy Sergey Andreevich , Fomichev Sergey Vladimirovich , Golovin Sergey Vladimirovich 
Published: October 2021

Abstract
The paper presents an algorithm for the search of the optimal frilling trajectory for a deviated well which is applicable for development of naturally fractured reservoirs. Criterion for identifying the optimal trajectory is the feature of the current study – optimal trajectory is chosen from the perspective of maximizing the positive effect related to activation of natural fractures in well surrounding rock masses caused by changes of the rocks stress-strain state due to drilling process. Drilling of a deviated well is shown to lead to the process of natural fractures in the vicinity of the well becoming hydraulically conductive due to drilling. The paper investigates the main natural factors – tectonic stresses and fluid pressure – and drilling parameters – drilling trajectory and mud pressure – influencing the number and variety of natural fractures being activated due to drilling process. An algorithm of finding the optimal drilling parameters from the perspective of natural fractures activation is proposed as well. Different theoretical scenarios are considered to formulate the general recommendations on drilling trajectory choice according to estimations of stress state of the reservoir. These estimations can be provided based on results of three- and four-dimensional geomechanical modeling. Such modeling may be completed as well for constructing geomechanically consistent natural fracture model which can be used to optimize drilling trajectories during exploration and development of certain objects. The paper presents a detailed algorithm of constructing such fracture models and deviated wells trajectories optimization. The results presented in the paper and given recommendations may be used to enhance drilling efficiency for reservoirs characterized by considerable contribution of natural fractures into filtration processes.
Geomechanical Modelling Application to Support Reservoir Selection for Carbon Dioxide Utilization and Storage
Authors: Korelskiy Evgeny , Petrakov Yuriy , Sobolev Alexey , Ablaev Anton , Mylnikov Danila , Melnichuk Dmitriy 
Published: October 2021

Abstract
During recent years reduction of carbon dioxide emission driving development of different technologies for CO2 capturing and utilization. Carbon dioxide injection in underground reservoirs is on of effective methods for storage or utilization as enhanced oil recovery agent. Selection of the potential reservoir for CO2 injection is critically important for long term gas storage. In this paper demonstrated software solutions and workflows for modelling of geomechanical modelling of CO2 injection.
Injection of CO2 into the reservoir entails a change in reservoir pressure and a change in reservoir temperature. In turn, the stress-strain state of the massif changes, which can lead to the destruction of the reservoir rock and host rocks, reactivation of faults, and, as a consequence, the loss of the integrity of the seal and uncontrolled interstratal crossflows. This paper will describe an example of choosing a reservoir for CO2 injection based on the study of the stress-strain state of the rock mass and its changes due to gas injection.
Currently, there are various approaches to CO2 recovery into the reservoir, including injection into depleted gas reservoirs, aquifers and oil reservoirs for the purpose of enhanced oil recovery. For injection planning, it is extremely important to understand both the initial injection conditions and their changes over time.
In the work on the published materials, the world experience of CO2 injection into the reservoir with the aim of its utilization was studied.
Using the tools of combined geomechanical modeling of the reservoir, the modeling of the change in the stress-strain state of the massif during the injection process was carried out and the conditions under which the destruction of the reservoir cap and the reactivation of faults occur. The influence of uncertainty in elastic-strength parameters on the critical state of the rock mass and the potential of the permissible injection volume is shown. Comparison of injection potential into reservoirs with terrigenous and carbonate seals has been performed.
Interdisciplinary Approach for Wellbore Stability During Slimhole Drilling at Volga-Urals Basin Oilfield
Authors: Norkina Anna Vladimirovna , Karpukhin Sergey Mihailovich , Ruban Konstantin Urjevich , Petrakov Yuriy Anatoljevich , Sobolev Alexey Evgenjevich 
Published: October 2021

Abstract
The design features and the need to use a water-based solution make the task of ensuring trouble-free drilling of vertical wells non-trivial.
This work is an example of an interdisciplinary approach to the analysis of the mechanisms of instability of the wellbore. Instability can be caused by a complex of reasons, in this case, standard geomechanical calculations are not enough to solve the problem.
Engineering calculations and laboratory chemical studies are integrated into the process of geomechanical modeling.
The recommendations developed in all three areas are interdependent and inseparable from each other. To achieve good results, it is necessary to comply with a set of measures at the same time.
The key tasks of the project were: determination of drilling density, tripping the pipe conditions, parameters of the drilling fluid rheology, selection of a system for the best inhibition of clay swelling.
Techno-Economic Assessment of the Equipment for Production Carbon Black from APG
Authors: Dimitriev Anton Sergeevich , Bandaletova Alexandra Alexandrovna 
Published: October 2021

Abstract
The present work describes one of the key areas of research activity of the modern oil and gas scientific world: decarbonization and increasing the efficiency of the natural and associated gas usage which is a method for producing carbon black. The technology is characterized by relative simplicity of the technological process and a wide market for the resulting product. This method is also included in the list of BAT (BREFs, 2020). The article presents a techno-economic assessment of the proposed method of using gas, there is also a comparison with other existing methods.
Comprehensive Assessment and Targeted Approach to the Implementation of the Gas-Lift Method of Operation on the Yamal Peninsula Novy Port Field
Authors: Blyablyas Aleksander Nikolaevich , Vershinin Sergey Anatolevich , Afanasiev Petr Nikolaevich , Mingazov Ayrat Anvarovich , Akhmetgareev Rustem Faridovich 
Published: October 2021

Abstract
As geological environment becomes more complicated, specifics of oil fields with high gas content more demanding, and the Company's requirements for assets development efficiency more stringent, new challenges arise that require application of high-tech approaches and new tools to solve the tasks set. The era of "easy" oil is far behind, and there are no "simple" tasks left, so the key goal of oil companies now is to radically improve efficiency of existing "difficult" fields including development of gas condensate reservoirs and oil rims.
The interest in development of new approaches to improve efficiency of the Novoportovskoye field is caused by the huge potential of the asset. Despite the fact that the field was discovered back in 1964, its remaining reserves are estimated at more than 250 million tons of oil and gas condensate and more than 270 billion cubic meters of natural gas, which are concentrated in five reservoirs. The Novoportovskoye field is the northernmost and largest on the Yamal Peninsula, but the complexity of its development and operation is caused not so much by geography and the lack of transport infrastructure but by the presence of a gas cap, low reservoir permeability, the occurrence of underlying water, and high gas content in produced reservoir fluid.
The high gas content complicates the production process. The main method of operation in the existing fields of the Yamal Peninsula is artificial lift by electric submersible pumps (ESP) on rental basis. Given the remoteness and isolation of the Arctic region, the high cost of equipment rental, and the low efficiency of ESPs in liquids with high content of dissolved gas, it is only fair to ask a question of whether there is a tool that may allow us to predict operation parameters for different lift methods.
The existing models and tools intended to assess behavior of the field are not good enough to fully predict gas breakthrough rates, optimize well operation parameters in case of short-term production forecasting, or select the optimal lift method.
In this paper, we described application of an integrated modeling process for a targeted assessment of well operation parameters at the Novoportovskoye field. Also, in the framework of this paper, we performed a technical and economic estimation of the options under consideration, and formulated some recommendations to improve efficiency of development and operation of the field under the impact of the existing complicating factors.
An Improved Methodology for Gas-Condensate Cluster Evaluations under Uncertainty
Authors: Melnikov Sergei Igorevich , Vershigora Nikita Vladimirovich , Groo Alexander Alexandrovich , Grigorev Denis Sergeevich , Kiselev Pavel Yurievich , Morozov Victor Victorovich 
Published: October 2021

Abstract
A decision to buy oil and gas assets requires a project evaluation (PE) aimed at integrated calculation of numerous possible scenarios of asset development, based on the uncertain resource values, variety of geological exploration program events, the most preferable decisions about the oil field development in the current economic conditions.
The vast amount of calculations determined by the probabilistic nature of the PE and specific timeframes require optimization of the current approaches based on the balance between accuracy and time. This issue is particularly relevant for the evaluation and analysis of gas or gas-condensate field cluster as the profitability of the project can be concentrated in the asset integration into one production cluster. Such option as well as proposal to gather separate fields to the common infrastructure, sequence of fields development with different geological and physical characteristics, calculations of a large number of synergy options, etc. require the multi-disciplinary team to think outside the box while searching for a business case. Thus, this paper is aimed to improve current approaches and the current tools adaptation which will be used to drastically automate cross-functional probability estimate of gas field cluster with technical and economic justification of sustainable integrated solutions.
The results were successfully validated within PE of several perspective gas condensate projects focused on the possibility of integration of the fields into a single cluster that creates additional value from the optimization of the project solutions (exploration, development strategy, gathering and transportation of hydrocarbons, monetization of the products) equal to tens of billions of rubles in a limited period of time.
Multivariant Well Placement and Well Drilling Parameters Optimization Methodology. Case Study from Yamal Gas Field
Authors: Magizov Bulat , Molchanov Dmitry , Devyashina Alisa , Topalova Tatiana , Zinchenko Ksenya , Kovalenko Alexander 
Published: October 2021

Abstract
More and more oil and gas fields are moving into the third stage of development - the stage of production decline. Oil and gas operating companies are looking for the most effective ways of production stabilization and extending the period of well exploitation. The most frequently used approach of improving exhausted reservoirs performance is reducing the pace of pressure and hydrocarbons production decline by well workovers and horizontal sidetracks drilling.
The most widely used type of new producing wells trajectory in low - and medium-amplitude gas fields, which include most of the Western Siberia gas reserves, is horizontal completion. According to the analysis carried out by two major Rosneft scientific centers, in oil saturated reservoirs with thickness less than 20 meters, the efficiency of horizontal wells with 300 meters length is 1.6-4 times higher than for directional wells, depending on the reservoir thickness and permeability. In gas saturated formations, the efficiency of horizontal wells performance relative to the directionally drilled wells in similar geological conditions is 3-6 times higher.
As the consequence of scientifically based well performance analysis the volume of horizontal wells drilling and horizontal side track completions at the assets of PJSC "NK "Rosneft" significanty increased as for the period from 2016 to 2021, Figure 1.
The Results of the Implementation of the Technology for Monitoring the Operation of Gas and Gas Condensate Wells According to Condensate to Gas Ratio to Optimize the Production of Liquid Hydrocarbons on the Vostochno-Makarovskoe Field
Authors: Nukhaev Marat , Rymarenko Konstantin , Baranov Vladimir , Grishenko Sergey , Zaycev Alexsandr , Aitkaliev Galymzan , Kabanov Vasily , Gusachenko Tatyana , Golubtsov Alexsandr 
Published: October 2021

Abstract
Liquid hydrocarbon production optimization is among key tasks in the gas condensate fields development. It depends on changes in gas supply quotas and on seasonal fluctuations in demand. The key point for such an optimization is the need to understand the current condensate-gas factor (CGF) for each well of the field to select the operating modes. Often, there is no sufficient well surveying data as these surveys are conducted not frequently enough. The paper presents an approach that allows monitoring the CGF for each well in real time and control the operating modes of the wells.
Setting a Development Strategy for Low-Permeable Turonian Gas Reservoirs
Authors: Kiselev Anton Nikolaevich , Degtyaryov Il’ya Sergeevich , Andronov Yurij Mikhaylovich 
Published: October 2021

Abstract
Synopsis. The paper describes approaches used when creating a comprehensive strategy for the development of low-permeable gas deposits of the Turonian age. Unlike to common techniques based on the experience of the previous development, the authors propose to optimize each of the constituent components of the development design, taking into account their contribution to the overall designing cycle. The efficient development strategy and technology will allow expanding the resource base of hydrocarbons at the expense of gas targets of the Turonian deposits, substantiating the efficiency of potentially promising areas of unallocated areas of the deposits.
Residual Water Saturation of Source Rocks of the Bazhenov Formation Western Siberia, Russia
Authors: Glotov Anton Vasilievich , Skripkin Anton Gennadyevich , Molokov Petr Borisovich , Mikhailov Nikolay Nilovich 
Published: October 2021

Abstract
The article presents a new method of determining the residual water saturation of the Bazhenov Rock Formation using synchronous thermal analysis which is combined with gas IR and MS spectroscopy. The efficiency of the extraction-distillation method of determining open porous and residual saturation in comparison with the developed method which are considered in detail. Based on the results of studies in the properties of the Bazhenov Rock Formation, a significant underestimation of the residual water saturation in the existing guidelines for calculating reserves was found, and the structure of the saturation of rocks occurred to be typical for traditional low-permeability reservoirs. The values of open porous and residual water saturation along the section of the Bazhenov Formation vary greatly, which also contradicts the well-established opinion about the weak variability of the rock properties with depth.
Seismic Reservoir Characterisation of Tyumen Formation in Frolov Megadepression
Authors: Grinevskiy Anton , Kazora Irina , Kerusov Igor , Miroshnichenko Dmitriy 
Published: October 2021

Abstract
The article discusses the approaches and methods to study the Middle Jurassic deposits of the Tyumen Formation within the Frolov megadepression (West Siberian oil and gas province), which have high hydrocarbon potential. The materials refer to several areas with available 3D seismic data and several dozen oil wells.
The problems of seismic interpretation and its application for geological modeling are considered. We also propose several ways to overcome them.
Reconstruction of the Near-Surface Velocities with Trap Bodies by the Full Waveform Inversion
Authors: Gadylshin Kirill Gennadievich , Cheverda Vladimir Albertovich , Tverdokhlebov Danila Nikolaevich 
Published: October 2021

Abstract
Seismic surveys in the vast territory of Eastern Siberia are carried out in seismic and geological conditions of varying complexity. Obtaining a high-quality dynamic seismic image for the work area is a priority task in the states of contrasting heterogeneities of the near-surface. For this, it is necessary to restore an effective depth-velocity model that provides compensation for velocity anomalies and calculates static corrections. However, for the most complex near-surface structure, for example, the presence of trap intrusions and tuffaceous formations, the information content of the velocity models of the near-surface area obtained based on tomographic refinement turns out to be insufficient, and a search for another solution is required. The paper considers an approach based on Full Waveform Inversion (FWI). As the authors showed earlier, multiples associated with the free surface reduce the resolution of this approach. But their use increases the stability of the solution in the presence of uncorrelated noise. Therefore, at the first stage of FWI, the full wavefield is used, including free surface-related multiples, but they are suppressed in the next steps of the data processing. The results obtained demonstrate the ability of the FWI to restore complex geological structures of the near-surface area, even in the presence of high-velocity anomalies (trap intrusions).