bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Open Hole Gravel Pack OHGP among the Technical Solutions for Successful Drilling and Completion of Horizontal Wells, North-Komsomolskoye Field, PK1 Formation
Authors: Salyaev Vadim V. , Sitdikov Suleyman S. , Nuykin Andrey M. , Arzamastsev Georgiy G. , Pilgun Pavel S. , Safin Ayrat F. , Gashimov Roman R. , Susoev Anton S. , Gruzdov Dmitry , Gromovenko Alexander , Kapkaev Alexander , Rezanov Ivan 
Published: October 2016

Abstract
Well completion using technology enabling to improve performance and life time is an important objective in the development of PK1 productive reservoir of North Komsomolskoye field. The main challenge of the development of this productive horizon lies in the fact that the reservoir is shallow (1,120 m TVD) and consist of poorly consolidated sandstone, which results in massive production of solids during operation. In addition to that, proximity of GOC and WOC together with high oil viscosity in reservoir conditions results in early gas and water breakthroughs when using standard completion technology.
Basic PK1 formation characteristics could be found in Table 1.
Remote location of the field and impossibility to use all-year-round road transport of materials, equipment and personnel are additional operating problems which had to be resolved to ensure that the project is delivered successfully and without extra costs.
Main questions which the project team had to deal with: What is the long-term solution to limit solids production at target drawdown to a level that would be safe for pumps and surface facilities?How to prevent early water and gas breakthroughs?How to drill a long horizontal section in poorly consolidate rock without any incidents knowing that previously several wells were lost in this zone due to well caving during drilling?
To tackle these problems, we chose a completion technology for the open horizontal section using screens equipped with autonomous inflow control devices (AICD) and inflow tracers. To ensure sand control, we injected gravel packing in the annular space between the screens and the open well bore. In addition to that, we built a 1D rock mechanic model to calculate well bore stability.
During the project execution we drilled 2 long horizontal sections without any incidents; tested completion technology with gravel packing (well A) and without gravel packing (well B); obtained the planned oil inflows; confirmed that the approaches adopted can be successfully used in the Full Field Development.
Given all the particular features of the field and the well design, this operation can be rightly considered one of the most complex onshore operations that have been performed in the Russian Federation.
Special Features of Casing Running and Cementing in ERD Wells
Authors: Netichuk Igor , Suvorov Anton , Galimov Amir 
Published: October 2016

Abstract
ERD drilling is associated with both technical and technological issues that need to be considered from the first planning stage which directly affects the job successful execution. The Paper summarizes the best practices and solutions related to casing running and cementing in ERD wells, describes the importance of geomechanics modeling, special features of casing running and cementing in ERD wells. The purpose of this Paper is to develop an understanding of recent solutions and best practices related to ERD wells construction from the very beginning.
Optimization of Oil and Gas Production Based on Integrated Planning
Authors: Volkov S. V. , Karandashova I. I. , Kagarmanov E. V. , Mogilnikov S. I. 
Published: October 2016

Abstract
One of the key directions for improving the efficiency of oil and gas production is the development of production management techniques. In the last 15 years, there has been a trend in the oil and gas industry toward introducing integrated organizational and management techniques and suitable tools into the production process. The world's leading participants in the oil and gas production sector are implementing programs to introduce "integrated operations" into the production process. In this article, the authors address one of the basic elements of integrated operations, i.e., integrated planning, including: key elements of the Integrated Planning process;key functional components of an Integrated Planning solution;examples of the use and optimization of an integrated plan.
Compressive Strength of Polymer Nanogels Used for Enhanced Oil Recovery EOR
Authors: Suleimanov B. A. , Dyshin O. A. , Veliyev E. F. 
Published: October 2016

Abstract
This paper presents the effect of light-weight metal nanofiller onto compressive strength of polymer gels used in Enhanced Oil Recovery. Non-destructive method based on ultrasonic-wave passing was applied for compressive strength evaluation. The investigations revealed effect gain in strength of gel system by 65% when addition of nanoparticles. The evidence of nanoparticles uniform distribution was utilized by measurements of electrical conductivity changes and percolation task. The kinetic mechanism of nanofiller effect on gel forming and determination of inflection points has been presented and proved. On the basis of polymer consumption due to nanofillers usage, it appears that it is economically efficient.
Investigation of Thermodynamic Processes During Multiphase Fluid Filtration to the Well with Perforation Channels in Damage Reservoir for Determination of Near Wellbore Zone Properties
Authors: Gaidukov L. A. , Novikov A. V. , Posvyansky D. V. 
Published: October 2016

Abstract
In this paper, new models of numerical simulation of non-isothermal multiphase inflow to the well are introduced. These models take into account a damaged near-wellbore zone with low permeability, perforation channels. With the models, it is investigated an opportunity of near-wellbore zone characterization and estimation its parameters (radius, permeability) based on the study of non-stationary downhole temperature and pressure data. Main factors of uncertainty are determined, their influence on the estimated parameters is analyzed.
Modeling Non-Equilibrium Dynamics of Condensate Recovery for Mature Gas-Condensate Fields
Authors: Lobanova O. A. , Indrupskiy I. M. , Yushchenko T. S. 
Published: October 2016

Abstract
Theoretical and experimental studies, as well as actual data of gas-condensate fields development, indicate non-equilibrium phase behavior at low reservoir pressures. However, matching of pVT-models and prediction of condensate (group C5+) recovery dynamics are performed on the basis of equilibrium constant volume depletion (CVD) experiments and simulations. This results in unreasonably high expected values of the condensate recovery factor and in selection of unappropriate technological regimes for reservoir development.
To simulate properly the actual dynamics of C5+ content in reservoir gas during revaporization (regular evaporation) at low pressures, one should consider non-equilibrium phase behavior of hydrocarbon mixtures. In this study, a numerical algorithm for simulation of the non-equilibrium constant volume depletion (NCVD) process is developed on the basis of the previously proposed model for non-equilibrium phase behavior and the non-equilibrium flash algorithm for calculation of phase fractions and compositions.
The NCVD algorithm and two pVT-models of reservoir hydrocarbons are used to simulate the dynamics of condensate recovery at Vuktylskoye field. A special procedure is used to match the pVT-models to lab and field data.
During the development of Vuktylskoye field, reservoir pressure has decreased from 36.6 MPa to 2.5 MPa, with the dew-point at 32.3 MPa. Non-equilibrium phase behavior is essential for gas-condensate reservoirs at pressures below the maximum condensation pressure. For the case considered, non-equilibrium effects are expressed in significant deviation of the actual curve of C5+-content in reservoir gas from the results of equilibrium experiments for pressures less than 5 MPa. The NCVD algorithm and the two pVT-models are used to simulate the dynamics of C5+-content in the reservoir gas at low pressures. A satisfactory match to the actual data is achieved for both the models by adjustment of characteristic relaxation time of the gas-condensate reservoir system to the value of about 30 years. This value, considering rescaling, is in good agreement with the experimental calorimetry data for non-equilibrium phase behavior. Equal values of characteristic relaxation time for both the pVT-models certify the possibility of physical simulation of nonequilibrium condensate revaporization by the NCVD algorithm regardless of specifics of a pVT-model previously matched to equilibrium experimental data.
Technology of Integrated Monitoring of Steam Chamber Evolution During the Oil Production from the Shallow Deposits of Super-Viscous Oil
Authors: Sudakov V. , Nurgaliev D. , Khasanov D. , Stepanov A. , Khamidullina G. , Kosarev V. , Galukhin A. , Usmanov S. , Zaripov A. , Amerkhanov M. 
Published: October 2016

Abstract
Currently the super-viscous oil deposits are under active development in the Republic of Tatarstan. The general method of production is Steam-Assisted Gravity Drainage (SAGD).
The problem of creation the complex of methods to monitor and control the reservoir processes caused by steam injection is of a great importance for increasing the development efficiency.
Traditional control methods of shallow deposits development are normally based on seismic survey and whether insufficiently adatped for shallow deposits of super-viscous oil or very expensive. Thus, the special modifications of geophysical methods are required.
The paper discusses general approaches used for creation of complex of methods for steam chamber monitoring the oil production from the shallow deposits of super-viscous oil by SAGD. The methods developed include seismic and geoelectric survey.
In context of integrated monitoring technique creation the set of special core survey was conducted to define the possibility of detection of the steam chamber distribution by seismic methods. The distinguishing feature of the monitoring technology developed is the use of downhole monitoring tools to receive the seismic signal and to perform the geoelectrical field establishing.
The article contains the description of the seismic data obtained processing methods and the results of the seismic data interpretation.
The study was made with the financial support of Ministry of Education and Science of the Russian Federation (project № №02.G25.31.0170)
New Approach for Oil and Gas Reservoir Simulation With Tilted Fluid Contacts
Authors: Mamedov Emil , Zakirov Ernest , Arekhov Vladislav , Ahmetzyanov Atlas 
Published: October 2016

Abstract
Contemporary traditional practice of 3D oil and gas reservoir modelling has severe drawback. Namely, the natural water flow is neglected. The main reason for this consist in complexity of combining two processes - the field development and natural water flow in the reservoir. This paper authors compared carefully four different approaches proposed by arabian and russian specialists for simulation of oil and gas reservoirs with tilted fluid contacts for using in software package of geological and hydrodynamic modeling. Advantages and disadvantages of the proposed approaches are revealed. Additionally, authors propose their own, the most realistic approach to taking into account the natural water flow for 3D simulation of oil and gas reservoirs with tilted fluid contacts and perfoming forecast calculations.
Integrated Approach to the Correlation Polyfacies Objects Deposits
Authors: Potapova A. S. , Finogenova A. S. , Zverev K. V. , Bregida A. A. , Erofeyev D. N. , Parfenova V. A. 
Published: October 2016

Abstract
This work develops and implements the principles of well and seismic correlation for detailing the structure of a target reservoir, BP16, in western Siberia. The authors used an integrated approach for the correlation of deposits based on core samples, which combines the advantages of a standard method of geophysical marker correlation and the correlation of events represented by cycles of sedimentation.
In the process of three-dimensional (3D) modeling of the field, simplification of the actual geological environment usually occurs. This allows the reservoir structure to fit a framework, which can be numerically modeled and then used for practical implementation. Often during problem solving, inversion of the procedures occurs. Using actual production data (oil-water contact, reserves amount, the scheme of well location, etc.), the geological understanding of the deposit is applied to the stratum-arched model because it is easier to understand and develop. Additionally, the accepted procedure is a serial study of geological and geophysical data, beginning with direct core data and not indirect geological materials, such as seismic and log data. The next phase includes well and seismic correlation followed by reserves evaluation and field development planning.
The proposed scheme avoids a situation where a simplified understanding of the field structure results in an incorrect strategy and injection system, breakdown of natural hydrodynamic barriers, increases in water cut, unknown fluid migration paths, and pressure changes in different parts of the oil pool.
A Novel Permeability Model of Naturally Fractured Shale reservoirs
Authors: Mi Lidong , Jiang Hanqiao , Li Junjian , Li Linkai , Killough John E. 
Published: October 2016

Abstract
Extensive pore-structure studies reveal that the fabric of shale systems are comprised primarily of micro-nano meter matrix pores and complex natural fractures. Measured permeability of shale samples containing natural fractures varies significantly with different cores in the same shale gas reservoir. The significant variation is mainly caused by the stochastic distribution of natural factures. These natural fractures’ effects on permeability under reservoir conditions significantly influence oil and gas production. This work proposes a predictive permeability model that considers the gas transport mechanisms both in the natural factures and matrix pores.
In this work, permeability variation is accomplished by considering that the shale core consists of matrix pores and natural fractures. A simple conceptual flow model with shale gas apparent permeability is developed that couples the cubic flow effects of natural fractures and micro- and nano- scale seepage effects of matrix micro- and Nano- pores based on the principle of equivalent flow resistance and the Tandem -Parallel rules of circuit theory. The matrix apparent permeability is derived based on the dusty gas model (DGM) by considering the contribution of Knudsen diffusion and gas slippage. The fracture apparent permeability is established based on a parallel-plate model by considering the influence of the fracture density. Then the comprehensive apparent permeability of shale samples is achieved by coupling the matrix apparent permeability and the natural fractures apparent permeability.
The matching results with experiment permeability of the Cambrian Niutitang formation from Sichuan Basin in South China show that the naturally fractured shale permeability is strongly affected by the natural fractures’ characteristic parameters. This research proves that shale measured permeability is the result of seepage interaction between the natural fractures and matrix space. The new permeability model, which overcomes the defect of conventional models that only considered the contribution of the fracture system or the matrix system, can accurately estimate the total contributions of matrix pores and natural fractures. In turn, this will enable engineers to complete the shale gas simulation studies more readily. In the future, this new methodology can be used to develop the next generation reservoir simulators for the shale reservoirs.
Lithofacies Modeling Application in Reservoir Simulation of Low Permeability Carbonates
Authors: Suchok Sergey , Obsharov Pavel , Ermilov Andrey , Volnov Ignatiy , Zhukov Aleksandr , Yalalova Venera 
Published: October 2016

Abstract
Nowadays there is observed a global trend of ever-increasing complexity and heterogeneity of hydrocarbon reservoirs. More challenging time makes companies take high-risk decisions based on long-term production prediction. As deterministic approach always gives a single result, it loses its relevance when we deal with risks. Generally probabilistic assessment methodology is coming to the forefront.
A new approach called RE-Status (Reservoir evaluation status) has been developed in this study. The methodology is based on probabilistic assessment and along with normal uncertainty technique it includes lithofacies modeling. RE-Status is based on six key parameters that allow us to understand reservoir complexity and level of project definition in terms of reservoir engineering.
Geological models were created by combining all geological and geophysical data in order to provide the highest-quality 3D representation of heterogeneous carbonate reservoirs. Evaluation of micro-macro heterogeneities and complex analysis of all core studies were used to derive lithofacies. Systematization of stratigraphic analysis, core descriptions and well logging data allowed us to locate facies in reservoir cross-section. It gave us better understanding of the reservoir and nature of filtration processes.
The new approach was applied to two gas fields. Impact of reservoir parameters and lithofacies variability on the dynamics of gas production was described. In the first case RE-Status helped to improve history matching by using facies and uncertainty analysis. In the second case (green field) production prediction based on the results of heterogeneity analysis and facies modeling allowed to locate sweet zones, optimize drilling strategy, increase reliability of forecasting and reduce the uncertainty range.
Novelty of the described approach is application of facies modeling to reduce key uncertainties, match the reservoir model to historical data and provide the most accurate forecast of production.
Strength Properties, Elastic Modules and Compressibility Factors of Rocks from Oil Fields OOO LUKOIL–Western Siberia
Authors: Vavilin V. , Kolpakov V. , Romanov Y. , Pustoshkin R. , Galiev T. , Kunakasov A. , Urazgulov R. 
Published: October 2016

Abstract
The purpose of our work – is to show our version of determining the strength properties, elastic modules and compressibility factors at reservoir conditions on the example of rock fields OOO "LUKOIL–Western Siberia". This paper briefly shows a method of measurement and processing of the results. The paper also shows some results of the determination of dynamic and static elastic moduli of rocks (Poisson's ratio, Young's modulus, shear modulus, compressibility, ultimate strength, elastic limits). This article also shows some results of a comparison of dynamic and elastic Young's modulus.
Static deformation and strength characteristics of the rock were determined by direct measurements of the longitudinal and transverse strains. All measurements were made at reservoir conditions by increasing the axial load until destruction of the sample. The rate of deformation changes was no more than 1.5 • 10-6 s-1, reservoir pressure and temperature were maintained automatically with a high degree of accuracy. Static deformation and strength characteristics are the most reliable, and reflect real properties of both homogeneous and heterogeneous anisotropic rocks.
In our laboratory, on by our optimized measurement method were performed investigations of dynamic and static strength properties of more than 500 rock samples from different oilfields of OOO "LUKOIL–Western Siberia". Our Company has received a very valuable information about the rocks in the form of diagrams "Stress–Strain," of Mohr's circles, elastic limits, ultimate strengths, elastic modulus, graphs of compressibility factor and Biot's coefficients depending on the pressures. It should also be noted that we have not been able to find any general and uniform dependence (laws) in all studied formations and fields, between dynamic and static elastic moduli. For solving of some specific tasks (for example, a field development, design of hydraulic fracturing) and for obtaining high–quality and reliable results on the rock mechanics we need use only static strength characteristics of rocks identified at true reservoir conditions.
Our methodology is based on the American Standard ASTM D 3148–93, and the results of our experimental work and the measurement procedure (Owner's Manual) for our equipment, taking into account the specific properties of sedimentary rocks of OOO "LUKOIL–Western Siberia". For concrete oil formations studied fields of OOO "LUKOIL–Western Siberia" we had found quite close links between the dynamic and static Young's modulus. Such petrophysical links is possible to use for obtaining more important information from the results of rocks research by dynamic method.
On One Precise Solution for Mobilisation Geo-physics and Geo-Mechanics of Hydrocarbons in Deformed Low-Permeable Reservoirs
Authors: Popkov V. I. , Khamitov I. G. , Zatsepina S. V. , Mitina E. V. 
Published: October 2016

Abstract
The group of authors considers the new globally area-specific geology of the trans-Volga and cis-Ural regions. It presents the geo-physically complex studies in geo-tectonics and correlated geo-dynamics. The authors provide the model of hydro-dynamic history matching in complex structured cavernous – fractured high-amplitude reservoirs with synergy in compaction of super low-permeable skeleton of porous cell containing organo-genic clusters of productive bioherms. The paper discusses the innovative method in development with due consideration of fracturing effect development in deformed prosody of petro-migration and diagenesis. The group of authors presents the new methods in search, exploration and development of complexly-structured hydro-carbon fields of the Zhiguli dislocation in the cis-Ural region.
They also present the additional complex seismic studies in the attributed of deformed synergy field with geo-physical rhythms, amplitude polarization in resolving the issues with compacted – de-compacted filtration. For complexly structured reservoirs having the deformed porosity and for adequate hydro-dynamic simulation of conjugated tectonics in fractured-cavernous-porous geo-mechanics the authors of the paper propose the complex geo-physical methods of investigation: seismic, laboratory and computer algorithmic geo-informative methods of adaptation. They also present the additional studies of vertically profiled anisotropy in geo-physically complex hydrodynamic models, in hydro-dynamic well studies, well work-over actions, multi-stage hydro-fracturing for low-permeable compacted heterogeneous, high-viscous and high water-cut oil and natural bitumen pools in due with dynamic area-specific capacity filtration properties, dual permeability – triple porosity for viscous-filtration and viscous elastic – diffusive complex development methods and stages for the production of hard-to-recover reserves.