bluuebunny/crossref_metadata_2025_split huggingface dataset:
Analysis of Self Flowing through Annulus of wells operated with Electric Submersible Pumps, Western and Eastern Siberia Fields Cases
Authors: Goridko Kirill Alexandrovich , Kobzar Oleg Sergeevich , Khabibullin Rinat Alfredovich , Verbitsky Vladimir Sergeevich , Litvinenko Konstantin Vladimirovich , Grishaev Maksim Stanislavovich 
Published: September 2020

Abstract
When operating production oil wells with electric submersible pump units in conditions of high free gas content in the pump, the mode of flowing through the annular (FTA) may occur due to a combination of factors, such as: relatively high pump intake pressure sufficient to maintain self-flowing conditions through annulus, large amount of gas coming to annulus, high degradation of ESP parameters which prevents decreasing BHP and others.
The authors of the article have reviewed literary sources, formulated the relevance of the problem of flowing in annular space of artificially lifted wells. The full characteristics of ESP was adapted by the results of flow loop tests with gas-liquid mixture. It made it possible to develop the model of ESP operation under FTA conditions, which was proven on field cases (four examples). Recommendations for FTA mode optimization discussed.
New Applications of Transient Multiphase Flow Models in Wells and Pipelines for Production Management
Authors: Yudin Evgeny , Khabibullin Rinat , Smirnov Nikita , Vodopyan Alexey , Goridko Kirill , Chigarev Grigorii , Zamakhov Sergey 
Published: September 2020

Abstract
The increase in the count of fields with deteriorating flow properties and, as a result, long nonstationary flow, leads to an increasing spread of periodic lift method.
Classic multiphase pipe flow models used by most commercial simulators are not able to account for transient processes occurring during intermittent operation.
The purpose of this work is to develop a method for calculating the pressure distribution in the wellbore and pipelines, taking into account the unsteadiness of the multiphase flow, as well as its testing on the example of solving various problems of production management: analysis of bringing wells on to stable production, monitoring and optimization of periodic well performance, analysis of processes during the start-up and shutdown of processing trains of the oil gathering system.
Submersible Low-Frequency Electric Motor Developed by LLC System-Service MC for Operation of Progressive Cavity Pumps
Authors: Vostrukhin Aleksandr 
Published: September 2020

Abstract
Today, traditional methods of lifting oil do not always provide the desired results. An inactive well stock is growing due to low profitability, so the company is actively looking for alternative, more efficient methods based on low energy and metal hardware. One of the effective methods is the use of the induction electric motor of the System-Service company.
Reservoir Connectivity and Compartmentalization Detection with Down Hole Fluid Analysis Compositional Grading
Authors: Gusev Sergey , Garaev Azat , Zeybek Murat , Kazakevich Eduard , Tsiklakov Alexander , Charupa Mikhail , Novikov Sergey 
Published: September 2020

Abstract
Kharyaginskoe field is located on the North part of Russia and produced by Zarubezhneft-Production Kharyaga company. The field is on the mature stage, so, it requires the special attention to drilling and production strategies optimization. The field is highly complicated by geological nonconformities (for example, faults), which has the crucial impact on the well productivity, recovery and reservoir management decision. So, the comprehensive understanding the zones complexities such as connectivity and compartmentalization is vital for optimal field development and has always been extremely challenging. The traditional method of using formation pressures for evaluation of reservoir connectivity does not perfectly work for the reservoirs under production as the fluid extraction disturbs the initial pressure equilibrium. This study shows another possible methodology of reservoir connectivity examination based on the analysis of hydrocarbon composition for three zones of Kharyaginskoe field.
Performance Monitoring of a Group of Yarudey Field Wells by Means of an Advanced Diagnostic Including Passive Acoustics and Temperature Modelling
Authors: Naymushin Anton , Zaripov Rustam , Aslanyan Irina , Kirpichikova Elena , Konovalov Stanislav 
Published: September 2020

Abstract
Flow and injection profile monitoring in horizontal wells enhances the oil and gas field development efficiency, which is of particular importance when the target reservoirs have a complex geological structure, as is the case with oil-rim reservoirs located below a gas cap. The objective of this paper is to present the results of multi-well diagnostics carried out in order to estimate the flow and injection rates in Yarudey Field wells (Russia) and assess the downhole completion integrity status.
When developing oil-rim reservoirs, flow and injection profiles need to be closely monitored so that gas and water breakthroughs along the length of thin beds and fractures could be promptly detected and appropriate remedial jobs planned. This task becomes more challenging in completions where multistage hydraulic fracturing was earlier performed, or the wells were cased with uncemented liners equipped with swell packers. To monitor the reservoir performance, advanced downhole diagnostics was performed in a group of wells in the field, where such reservoir-oriented techniques as passive acoustics and high-precision temperature logging were used. Application of the passive acoustic logging technique helped to identify reservoir flow zones and detect crossflows behind casing. The flow and injection rates were estimated through temperature simulations. Both these techniques were found to be useful, including those instances when the integrity of complex downhole completions was to be assessed. On the whole, the obtained results have proved the effectiveness of supplementing conventional production logging (PLT) with reservoir-oriented techniques.
Integrating Experience and Developing Recommendations to Aid in Formation Testing Jobs Planning in Various Geological Conditions
Authors: Chashkov Anatoliy Vasilevich , Shalamov Ilya Pavlovich , Shkunov Evgeny Viktorovich , Bakustina Svetlana Viktorovna , Yarullina Alfiya Ilfatovna , Listoykin Dmitriy Aleksandrovich , Novikov Sergey Vasilevich , Charupa Mikhail Viktorovich 
Published: September 2020

Abstract
The objective of this work is to summarize obtained information during the well formation testing (WFT) jobs completed in open hole at the fields of PJSC NOVATEK. We also conducted analysis of formation pressure measurements, assessment of the saturating fluid type and the quality of downhole fluid samples collected at various geological and well conditions. Now PJSC NOVATEK and its subsidiaries have been actively using various types of WFT to solve a complex geological objective on the fields at exploration and development steps. Thus, an impressive array of data was formed, and detailed analysis made it possible to develop optimal success criteria and recommendations for carrying out such jobs in the wells.
We used data obtained with WFT jobs in the main productive reservoirs of the Cenomanian, Marseilian, Tanopchin and Achimov strata in the northern region of Western Siberia.
We have considered influence of various geological and technological factors on the reliability on formation pressures (FP) measurements with WFT. To assess the quality of downhole fluid analysis (DFA) we tried to compare time to reservoir fluid appearance, reservoir properties, drilling fluid type etc., in dependence of sampling tool type utilized.
Within performed interval pressure transient tests (IPTT) an analysis of the quality of the hydrodynamic parameters of the reservoirs was conducted aiding to plan cased hole well-tests.
We also considered of WFT application for representative downhole sampling to obtain information of the main PVT properties of reservoir fluids.
Experience in the Implementation and Research of Multilateral Horizontal Wells in the Vankor Cluster Field
Authors: Volkov Vladimir Alekseevich , Shirokov Andrey Sergeevich , Grandov Dmitry Vyacheslavovich , Utusikov Yaroslav Vladimirovich 
Published: September 2020

Abstract
The paper presents an assessment of multilateral horizontal wells performance, which is relevant for the conditions of the Vankor Cluster of fields in view of the beginning of active development phase to involve low-productive reservoirs of Nizhnekhetskaya Formation into development.
With the development of the asset reserves, a natural decrease in input productivity is observed in the zones with poorer properties. This circumstance requires the introduction of new promising technologies, such as multistage hydraulic fracturing in horizontal wells (Hz wells with MHF) and drilling multilateral horizontal wells (MHz) which have already proven themselves on the positive side under similar conditions in the fields of West and East Siberia.
Application of the Multi-Stage Hydraulic Fracturing Technology in Horizontal Wells with Large Vertical Outflow to Improve the Development Efficiency of Reservoirs with Deteriorated Filtration-Capacitance Properties at the Sakhalin Shelf Field
Authors: Prudskiy Mikhail Yurevich , Khaliulin Ruslan Rinatovich , Shakirov Roman Akhatovich 
Published: September 2020

Abstract
The article presents the projected results of the offshore development option in the zone of deteriorated filtration-capacitance properties. To involve additional oil reserves in the development, it is proposed to use multi-stage hydraulic fracturing technology at the projected horizontal wells. The analysis was executed using modern methods of geological, hydrodynamic and geomechanical modeling. Method of most favorable zones’ isolation for carrying out multi-stage hydraulic fracturing of formation based on maps of permeability, current formation pressure, density of residual movable oil reserves and cover power is proposed. Taking into account the selected zones and the expected direction of crack development, the trajectories of new horizontal wells with a large deviation from the vertical were optimized. Efficiency assessment was carried out by comparing the technical and economic parameters of the proposed development option (horizontal wells with multi-stage hydraulic fracturing of the formation) with the basic version (horizontal wells with traditional completion). A hydrodynamic model was used to calculate oil production levels according to options.
As a result, it was proved that the use of multi-stage hydraulic fracturing technology will involve additional oil reserves in the development and increase the efficiency of expensive offshore drilling.
Estimation and Localization of Residual Recoverable Oil Reserves by the Complex of Filtration, Optical and Field Research
Authors: Burkhanov Ramis Nurutdinovich , Lutfullin Azat Abuzarovich , Ibragimov Ildar Ilyasovich , Maksyutin Alexander Valeryevich 
Published: September 2020

Abstract
The structure and composition of oil reserves deteriorate in the course of a mature oil field development due to geological and technological factors. The geological factors include vertical and lateral macro-and micro-heterogeneity of the reservoirs under development. At the same time, macro-heterogeneity leads to the formation of bypassed residual oil in low- permeability and stagnant layers, zones and lenses that are not exposed to stimulation, while micro-heterogeneity contributes to the formation of residual reserves of capillary oil and oil films. Technological factors include impossibility to fully account for reservoir heterogeneity when substantiating well spacing, pressure gradient, or flooding technology. The key problem here is the lack of clear understanding of the distribution pattern, quantity and deterioration of the quality of residual oil in water-flooded reservoirs, which makes it challenging to reasonably select a technology for effective oil extraction.
Despite the improvements constantly made to the production logging, hydrodynamic and interpretive, seismic, lithofacies and other methods of exploration and residual reserves modeling, it is often impossible to obtain timely reliable information about the percentage of reserves depletion and their coverage with the development activities. This paper proposes another method — optical — that, in combination with well logging and hydrodynamic surveys as well as geological and hydrodynamic simulation, has been tested to assess the quantity and spatial pattern of residual oil reserves of the Kynovian (Do) and Pashian (D1) horizons at the experimental site of the Romashkinskoye oil field (Devonian formation). From the theoretical and methodological standpoint, this method is underlain by the results of in vitro studies of core columns and involves the selection and research of optical properties of oil wellhead samples, mathematical processing and correlation of the obtained optical and field data. The obtained estimate of residual reserves is compared with data derived from geological simulation, the most promising automated method for identifying, geometrizing and calculating residual recoverable oil reserves (RROR).
The proposed method offers such advantages as ease of use, promptness, reliability, functionality and cost-effectiveness. It uses actual data on cumulative well production and takes into account the current reservoir and fluid porosity and permeability (P&P), which provides the possibility to obtain more precise estimates of the RROR quantity and spatial pattern.
Pressure Maintains System Optimization Recommendations by Integrated Analysis of Well-Tests, Logs and Pulse-Code Interference Tests
Authors: Ganiev Bulat , Lutfullin Azat , Karimov Ildar , Muhliev Ilnur , Gulyaev Danila , Farakhova Rushana , Zinurov Linar , Mingaraev Ramil , Aslanyan Artur 
Published: September 2020

Abstract
In order to efficiently asses pressure support during the field development that bears a complex structure of the void space, it is extremely important to understand how existing wells affect each other, this issue was solved at one of the fields in Tatarstan through unique cross-well surveys.
The conventional way to solve the problem of assessing reservoir connectivity consists of analysing seismic surveys, analysing the tectonics and sedimentology at focus region, conducting tracer surveys, interference tests, and production analysis. However, all of aforementioned methods display substantial deficiencies, for instance: poor seismic sensitivity towards low-amplitude faults, poor degree of detail of tectonic analysis, poor tracers representatives in complex vertical and lateral reservoir heterogeneity, if most permeable thin layer lateral anisotropy differs greatly with the main layer anisotropy, huge production losses during interference test along with receiver well shut-ins, and ambiguity in the estimation of interference with the production analysis. That's why is was decided to use pressure Pulse Code Testing (PCT) (Kamal, M. M. 1983; Ahn, S. et al. 2010; Aslanyan, A. et al. 2015; Aslanyan, A. et al. 2016) that managed to overcome those problems and avoid production deferment. The values of reservoir diffusivity and transmissibility are calculated from the recorded in revisers moment of arrival and the amplitude of the pressure disturbance from rate changes in generators. Based on the registered pressure pulse amplitudes we can estimate the influence of generator monthly injection on the pressure at receivers (Myake-shev, N. 2017). The obtained injector influence on producing well is extremely low, and indicates a poor efficiency of pressure maintains system at the tested area. That implicitly indicates on unproductive injection (Zheng, S. 2010).
In addition to a subsequent production logging it was confirmed that there is in fact a presence of a significant amount of unproductive injection due to cross flow downstairs. That was reducing the efficiency of the pressure support in the study area. This placed the start to a set of extended surveys aimed at selecting of the most appropriate injection targets of the injection wells to improve the efficiency of the pressure maintains system as well as oil production increase.
Missed Net Pay Zones Mature Oilfieds Via Injection Of Expert Knowledge in Deep Learning Algorithms
Authors: Semenikhin Artyom Sergeevich , Shchepetnov Arseniy Andreevich , Reshytko Alexander Alexanderovich , Sabirov Arthur Rustamovich , Osmonalieva Oksana Taalaevna , Egorov Dmitry Vitalyevich , Belozerov Boris Vladimirovich 
Published: September 2020

Abstract
In this work we pursued the goal of an automate cognitive system development capable for searching missed net pay zones within wells to extend a brownfield lifecycle via the involvement of new reserves into the field development. Additional research was dedicated to studying the possibility of knowledge transfer across different fields and the construction of the ranking model allowing fast expertise conduction of proposed intervals and evaluation of the proposed method on mature assesses.
The proposed approach is based on deep learning and artificial neural networks architectures trained in a supervised mode using a provided human well logs interpretation. Our approach also utilizes transfer learning procedures in order to reuse knowledge extracted from the oilfield with sufficient data and improve the predictive qualities of the model on a target oilfield. Additionally, we proposed a ranking model that simulates expert decision-making process and evaluates oil saturation potential of proposed intervals by sorting it by a confidence level.
Developed method was evaluated at the one of Gazpromneft brownfields, located in Western Siberia, Yamalo-Nenets region. The model was trained on a data from this field and its analogues with subsequent reinterpretation of the whole well log volume. Several hundreds of new net pay intervals were proposed and post-processed by ranking model. Then the list of proposed intervals was analyzed by an expert group including number of geologists, petrophysicists and reservoir engineers. Significant part of these intervals after detailed and comprehensive evaluation were marked as missed during previous manual well log interpretation conducted by petrophysicist and taken for the following fieldwork. Produced results confirmed applicability of proposed algorithm and proved its capability for localization of previously unrecognized net pay intervals.
3D Reservoir Model History Matching Based on Machine Learning Technology
Authors: Illarionov Egor , Temirchev Pavel , Voloskov Dmitry , Gubanova Anna , Koroteev Dmitry , Simonov Maxim , Akhmetov Alexey , Margarit Andrey 
Published: September 2020

Abstract
In adaptation of reservoir models a direct gradient backpropagation through the forward model is often intractable or requires enormous computational costs. Thus one have to construct separate models that simulate them implicitly, e.g. via stochastic sampling or solving of adjoint systems. We demonstrate that if the forward model is a neural network, gradient backpropagation becomes naturally involved both in model training and adaptation. In our research we compare 3 adaptation strategies: variation of reservoir model variables, neural network adaptation and latent space adaptation and discuss to what extent they preserve the geological content. We exploit a real-world reservoir model to investigate the problem in practical case. The numerical experiments demonstrate that the latent space adaptation provides the most stable and accurate results.
Tool for Operational Well Stock Management and Forecasting
Authors: Sharifov Anar Rabilovich , Perets Dmitry Sergeevich , Zhdanov Ivan Aleksandrovich , Belonogov Evgenii Valerievich , Margarit Andrei Stanislavovich 
Published: September 2020

Abstract
The purpose of the article is describing a tool for analysis and waterflooding management of large fields with a long development history. The developed tool contains a physical and mathematical model of the reservoir, which is a self-consistent solution of the equations of material balance, filtration and PVT correlation for each waterflood cell. To verify a simplified reservoir model, it is possible to forecast using historical well control parameters with their automatic adaptation. The paper describes the main stages of user interaction with the tool and its functionality. The results of a retrospective forecast for two different development reservoirs has been presented, the lacks and conditions of the model applicability were described. Integration with the tool on the basis of optimization algorithms was made and the results of multivariate calculations for the search for a scenario for developing a large oil and gas field with the best economic effect are presented.
Thomsen Parameters Determination from Synthetic Sonic Logging Data for VTI Formation Using a Convolutional Neural Network
Authors: Bazulin Maksim , Sabitov Denis , Charara Marwan 
Published: September 2020

Abstract
Vertical transverse isotropic (VTI) formations are commonly encountered in sedimentary basins and they are the simplest type of anisotropic formations. However, the inversion of the sonic logging data in such formations is a challenging problem for the case of wells parallel to the axis of symmetry. Most of the conventional processing techniques use only the kinematic characteristics of the wavefield, whereas sufficient information about the anisotropic parameters is contained in the amplitudes of the signal. All the elastic parameters (formation density, compressional and shear wave velocities, Thomsen parameters) cannot be retrieved without rigorous assumptions or additional data (e.g. from deviated borehole). In the present work, we perform a sonic data inversion by using a machine learning approach, more specifically, the convolutional neural network. The main advantage of the method is that the neural network processes the full waveform seismogram taking into account simultaneously the kinematic and the amplitude part of the wavefield. For the network training, a synthetic dataset was generated using the spectral element method. The results of the work demonstrate the feasibility of the method, when a seismogram is fed to the input of the neural network and elastic parameters are given as the output.
Developing Algorithms to Analyze Data Gathered During Drilling Using Big Data Approaches – Features, Limitations, Main Rules
Authors: Zinovyev Alexey Alexeevich , Nechaev Artem Valentinovich , Ocheretyanyy Anton Nikolaevich , Volkov Dmitrii Yurievich , Petrakov Yuriy Anatolyevich , Sobolev Alexey Evgenyevich 
Published: September 2020

Abstract
The paper describes the main approaches used in the development of predictive analytics algorithms, both of a general nature and in the field of well drilling. When describing the algorithms used, the basic assumptions of each and the ensuing limitations of the developed model are explained. The necessity of building hybrid models, involving the full amount of information collected, including calculations carried out during the construction of the well, both from the engineering and geological sides, is shown. The paper discusses the culture of working with data in the oil and gas field in general and in particular well drilling. The current level does not allow companies to create scalable solutions of predictive analysis. As a result of the work done, the basic rules were proposed, the first step was taken towards standardizing the process of collecting and analyzing information flow arising during the construction of wells.