bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reduce Well Construction Time by Using PDC with Rolling Depth of Cut Control Element in Carbonates Formations
Authors: Rebrikov Andrey , Koschenkov Anton , Nelaev Artem , Trefilov Maxim 
Published: October 2019

Abstract
In the current exploration and production practices, drilling is entering a new stage of development in which one of the top priorities is the reduction of well construction time with new technologies and innovations. A key component of this effort is the use of the latest achievements in the design and manufacturing of drill bits. To efficiently drill complex well profiles with a bottomhole assembly (BHA), including a downhole positive displacement motor (PDM) and polycrystalline diamond compact (PDC) bits, special attention is paid to controlling and orientating the bit by using the cutters depth of cut control limitations. The bit depth of cut is a quantity that characterizes the bit axial displacement per one revolution and depends on the bit rotation speed and rate of penetration (ROP). The control of the depth of cut enables the adjustment of the reactive bit torque, depending on the weight on the bit (WOB) as a result of the use of different static fixed depth of cut control (DOCC) elements, which have their own disadvantages and limitations.
The rolling depth of cut control (RDOCC) element is an innovation that was used to reduce excessive depth of cut by PDC cutters while drilling medium, hard, and interbedded rock. This technology has enabled PDC bits to achieve the best footage and ROP results because it provides smooth drilling and improved bit steerability.
Field trials of this technology have shown its high efficiency in interbedded heterogeneous rock drilling of different well profiles, as compared to conventional depth of cut control static elements.
The first field trial in Russia proved the effectiveness of RDOCC element technology. The RDOCC innovation helps oil companies to achieve new results and improve drilling performance; the ROP and footage drilled on the bit improved. In some fields, it became possible to drill the entire section interval with one run, whereas two or three PDC bits were typically used previously. This paper describes the benefits of using the new drill bits with the RDOCC elements in challenging drilling applications with complex geological conditions.
Integrated Approach to Construction Wells on the Achimov Deposits
Authors: Shokarev Ivan , Glebov Evgeny , Bannov Evgeny , Erokhin Dmitry , Polchenko Valery , Litvintsev Ivan , Shakurov Rafael , Kravchenko Andrey , Levin Ilya 
Published: October 2019

Abstract
Construction wells on the Achimov deposits was accompanied by many problems: the danger of sticking and oil, gas and water inflow; a serious decrease in the mechanical ROP on dense layers; severe downhole conditions: vibrations on dense interlayers, temperature up to 110°C, drilling mud based on diesel fuel. All of the above issues increased the number of trips due to equipment failures, increased non-productive time and, as a result, increased the well construction period. The integrated approach described in this work has significantly reduced non-productive and well construction time.
The customer was suggested: –Limitation the mechanical rate of penetration (ROP) by 15m/h to control equivalent circulating density;–Control of the equivalent circulation density by the MWD sensor;–Combination of a modular motor with rotary steerable (RSS) system in bottom hole assembly (BHA) to increase the mechanical ROP during drilling in dense layers of the productive horizon;–Optimization of the bit design, taking into account geological features, meanwhile drilling with a rotary-steerable system;–Use of a new generation rotary- steerable system;–Optimization of the BHA;–Modernization of equipment preparation procedures.
An integrated approach to drilling wells on the Achimov deposits with new methods and technologies offered to the customer allowed reducing the number of failures by 100-200%, which reduced the number of runs, and as a result, the non-productive time decreased. The reduction in the number of runs allowed taking from 500 − 600 meters to 1200 − 1500 meters per run. Optimization of the bottom hole assembly, including a new bit design in Russian Federation, integration of a new generation of rotary-steerable system with a modular motor, made possible to expand the boundaries of drilling modes, accordingly increase the mechanical rate of penetration. In addition, the adopted methods and technologies allowed reducing the negative impact of vibrations that occur during the drilling of dense layers.
Application of the integrated approach to solve the problems, which took place during the construction of wells on the Achimov deposits, has significantly reduced: the number of equipment failures, non-productive time. Meanwhile increased the mechanical rate of penetration and drilled distance in one trip, which in general has significantly reduced the time of well construction.
Modeling of a Gas-Lift Well Operation with an Automated Gas-Lift Gas Supply Control System
Authors: Yudin Evgeny , Khabibullin Rinat , Galyautdinov Ilyas , Andrianova Alla , Goridko Kirill , Smirnov Nikita , Babin Vladimir , Chigarev Grigory , Lomukhin Igor , Murzaev Yaroslav 
Published: October 2019

Abstract
Gaslift operation faces several challenges - optimizing the amount of gas pumped, ensuring that the gas is pumped to the maximum possible depth, combating salt and hydrate formation and, finally, the instability of the flow. The timely detection of these problems and the optimisation of the system requires information on the dynamics of the main parameters (flow rates, pressure measurements at each unit and the amount of gas pumped). In the conditions of high cost of multiphase flowmeters at the Orenburg field well flow rates are not measured often enough, and the task of identification of the most unstable wells in real time by auxiliary parameters measured with greater discreteness becomes urgent.
Often important production decisions based on monthly data, and less often on daily measurements. In the paper the necessity to go down to the level of analysis of highly discrete information (dozens of measurements per day) is proved by the example of the Orenburg field, because in conditions of unstable operation the averaging inside the day can lead to distortion of the general view of the operating mode. Within the framework of the analysis of dynamic parameters of gas-lift wells operation in unstable conditions, the notion of well operation quality index was introduced, i.e. a normalized metrics reflecting the general state of stability of a gas-lift well operation. This metric considers uncoordinated changes in the main parameters of the system. The wells with the lowest index are the first candidates to search for hidden production losses (not achieving the regime flow rate).
Modelling of well performance, adaptation of models to historical data - a typical approach to production management in the field. But in the conditions of unstable gas-lift wells modeling of their work is much more complicated. In this regard, the authors of the article developed an approach to modeling wells through the approximation relationship between the flow rate of wells and the flow rate of gas-lift gas and linear pressure with further integration of well models with the collection system.
To solve well operation modes optimization problem, an integrated Proxy-model of the asset was created, which consists of a simplified reservoir model, developed well models and infrastructure model. The Proxy model was adapted and verified to the actual operating data. The task of finding the optimal distribution of gas injection between the wells from the point of view of oil production was solved.
Efficiency Analysis of ESP Lifted Wells in the Context of Virtual Flow Metering
Authors: Krylov Ilya , Budennyy Semen , Khabibullin Rinat , Loginov Aleksandr , Andrianova Alla , Kobzar Oleg , Margarit Andrey 
Published: October 2019

Abstract
Due to need for optimal management of a large wells stock with a relatively limited amount of conditioned data, the need for a focus rapid detection of implicit complications in the work (mechanical wear of the working bodies of the pump) and an increase in overhaul period of submersible equipment increases. Real-time monitoring of all wells in the debit is limited due to infrastructure problems and high costs of measuring activities. Despite this, the possibility of such monitoring is not excluded due to the availability of field information that correlates with the well flow rate and the mode of its operation.
The article presents an algorithm that, based on telemetry ESP to estimate the parameters that affect the performance of the well and submersible equipment, such as the coefficient of degradation of the outlet characteristics of the pump, the actual efficiency (coefficient of performance) of ESP and the thickness of the deposition of paraffin on the inner walls of the tubing.
When processing field data, the parameters correlating with the well flow rate were revealed, which allowed to build a model of a virtual flow meter to verify the existing flow rate measurements and restore the missing values. The basis of the physical and mathematical approach is an algorithm that connects the parameters of the ESP system with the flow rate through the power consumption and hydraulic calculations of the gas-liquid mixture flow in the tubing. After preliminary calibration of pressure-flow characteristics of ESP for real mode of operation, daily measurements of fluid flow rate with a periodicity of 1 hour were calculated.
Implementation of Different Types Flowmeters for Gas Lift Metering on Orenburgskoe Field
Authors: Rymarenko Konstantin , Nukhaev Marat , Grishenko Sergey , Chernysh Nikita , Titov Sergey , Zaycev Alexander , Dadakin Nikita , Ulyanov Vladimir 
Published: October 2019

Abstract
Gas or liquid flow control is one of the most important technical tasks in the oil and gas industry. The choice of a particular device most often occurs on the basis of the established practice of application in a particular company. This paper presents the experience of Gazpromneft-Orenburg in the use of overhead and stationary flow meters of various types, including ultrasonic and restriction devices for measuring gas-lift gas in the Orenburg oil and gas condensate field.
Successful Application of the Intelligent Inflow Tracers for Monitoring of Horizontal Wells on North Komsomolskoe Field
Authors: Solovyev Timur , Soltanov Dzheykhun , Galimzyanov Artem , Naydenskiy Konstantin , Nukhaev Marat , Mukhametshin Ilkam 
Published: October 2019

Abstract
Most of the new oil fields in Western Siberia have unfavorable conditions for field development such as excessive gas cap presents, oil rims and active water aquifer. The North-Komsomolskoe oilfield is also characterized by poor consolidated sandstone and high viscous oil. Different types of reservoir completion (ICD, ACID, AICV) have been decided to trial test for this field in order to mitigate early water or gas breakthrough along the long horizontal well. During this trial testing of the optimum type of lower completion, the continuous well monitoring is required; clean-up efficiency estimation after drilling, quantitative estimation of inflow per compartment along the wellbore and localization of water or gas breakthrough. Traditional well logging methods like production logging cannot always be easily applied technically and be cost-effective for many surveys during well life. This article presents the result of using a novel technology based on chemical tracer for continuous well monitoring.
Polymer matrix with chemical markers for oil and water have been integrated into different types of lower completion (ICD, AICD, Stand Along Screen) and run into the hole as a part of liner string. Technology of intelligent chemical tracers is used to monitor well performance over a long period of well life, which allows to obtain the following information: effectiveness of clean up operation after drilling, inflow per compartment and water/gas breakthrough localization zone. To confirm interpretation results based on chemical tracer, the traditional method (production logging) was used to measure inflow along the wellbore and compare with result from tracer survey.
Building More Accurate Models for Different Reservoir Types Using Interval and Interference Pressure Transient Testing
Authors: Zeybek Murat 
Published: October 2019

Abstract
Building accurate reservoir models can be quite challenging, especially highly stratified thick intervals in hydraulic communication in reservoir. Presented methodology is based on comprehensive Interval and Interference Pressure Transient Testing (IIPTT) for classified reservoir types with a systematic approach. Classification of reservoir types is based on layering, thickness, and hydraulic communication of layers in the reservoir.
The methodology describes building more accurate anisotropic reservoir models, providing well performance assessment based on integrated comprehensive IIPTT solving with efficient non-linear parameter estimation and modeling with numerical simulation for different reservoir types. The number distributed IIPTTs are optimized to ensure to achieve coverage across total thickness depending on the reservoir type.
It is demonstrated that high resolution accurate reservoir models can be built for relatively thick highly layered reservoirs in a feasible manner. In addition, field examples with classified reservoir types including flow tests supported the methodology.
Unrestricted Pressure-Transient Solutions for Homogeneous and Composite Elliptical Flow Models with Limited and Full Height Inner Boundary
Authors: Larsen Leif 
Published: October 2019

Abstract
Pressure-transient solutions for homogeneous and composite elliptical flow models have been presented by several authors over the past 40 years, but all have computational limitations, either with respect to time range or degree of eccentricity of elliptical boundaries. This paper removes these limitations on time and eccentricity with a new fully flexible computational scheme for unbounded and bounded homogeneous and composite elliptical flow also extended to cases with a limited-height inner boundary, thus also covering horizontal well scenarios in composite elliptic models.
Kuchuk and Brigham's (1979) Laplace-space solution is fully flexible with respect to the shape of ellipses, but has a lower limit on time that does not reach purely linear early data unless slow extended precision computations are used. However, this limitation can be removed with the approach of Riley et al. (1991) using asymptotic expansions for early data and Kuchuk and Brigham's (1979) solution for late data. This works for a fracture as inner boundary but has restrictions on the outer boundary. Another asymptotic expansion was used by van den Hoek (2016) to derive a more flexible but not fully flexible solution, since limitations remain for highly eccentric scenarios. This paper extends results from these references with other asymptotic expansions to achieve full flexibility on time and eccentricity.
A wide range of examples are included to highlight the flexibility and utility of the new solutions, with cases ranging from damage-zone dimensions to long-time injection-falloff scenarios, but only as stationary cases with emphasis on the dimensions of the scenarios. Contrasts between exact degenerate elliptical models and standard solutions for infinite-conductivity fractures based on uniform-flux models and an equivalent pressure point are also discussed briefly. This concerns a solution artifact that might be overlooked. With a limited-height fracture used as a horizontal well replacement, cases are also included for horizontal wells in composite elliptical models.
Approach to Determining the Optimal Parameters of Well Performance in Fractured Reservoirs with a Gas Cap: Orenburg GCF Case Study
Authors: Yudin Evgeny , Galyautdinov Ilyas , Piotrovskiy George , Morozova Anna , Kolyuk Olesya , Smirnov Nikita 
Published: October 2019

Abstract
The paper deals with the features of well operation at the Orenburg oil and gas condensate field. Our study presents the investigations of the reasons for various complications, which can lead to the reduction of production characteristics of wells for the conditions of fractured reservoirs with gas cap and high gas content of oil. The Orenburg oil and gas condensate field wells are used as an example to present the results of well production optimization in accordance with the obtained results. In this paper we proposed a complex approach to determining the parameters of the fractured formation. At the first stage, based on the mathematical model of Warren-Root fracture reservoir, we found the dependence of the well flow rate on time and parameters of fracture under conditions of maintaining constant bottomhole pressure. The second stage was a generalization of this problem for the case of arbitrary dynamics of flow rates and pressures based on the problem of deconvolution. The search of parameters of double fracture formation was carried out by their variation in the corridor of admissible values in order to minimize the deviation of the calculated flow rate relative to the true one.
Big Data in Field Development Projects
Authors: Gurianov Andrei , Katashov Alexander , Ovchinnikov Kirill , Saprykina Kseniya , Novikov Igor , Malyavko Evgeny , Kiselev Vasily 
Published: October 2019

Abstract
In recent years, new terms and concepts have appeared that describe the digital transformation currently in progress. The world image, including in the industrial world, has been changed by the concept of intelligent enterprise (IE) - a set of technological innovations, including artificial intelligence (AI), intelligent automation (IA), deep learning technologies, predictive analytics and cognitive computing. The increasing complexity of the oil and gas business and the decreasing optimization potential from traditional approaches require the use of new, innovative digital technologies to remain competitive.
Responding to the market conditions of falling hydrocarbon prices, the oil and gas industry is increasingly mastering Big Data to optimize technological processes and prevent accidents. The emergence of Big Data technologies, predictive analysis and machine learning are changing the general image of many industries, and the oil and gas industry is no exception. New players are quickly emerging throughout the industry, and digitalization will affect the entire value chain throughout in the oil and gas industry. Among the most promising segments for the transition to digital technologies are asset management and infrastructure facilities, field development, geophysical services, pipelines and processing.
Digital technology is the most powerful driver for cost reduction. It is expected that implementing these solutions will, by 2030, reduce the costs of E & P projects by up to 30%. Thus, Russia can leverage these new technologies and retain a share in the world energy market for another 50 years. The oil industry has recently passed the most difficult period in the last 30 years. The fall in oil prices since 2014, the reduction of 350 thousand employees worldwide, and fall in production investment are examples of serious challenges that the industry has faced in recent years. These challenges have resulted in new attempts to optimize business through implementing new technologies to improve the efficiency and profitability of companies.
ESP Energy Efficiency Management as a Key to Cost Savings and Runlife Improvement
Authors: Musorina Anastasia , Safonov Bictor , Terebennikov Valery 
Published: October 2019

Summary
In current conditions of oil and gas production the highest importance is improvement of the company operational performance, and with increase of electric power tariffs in the market the porting of costs for energy in total scope of the Company costs is continuously growing maintaining the trend of such growth. In Salym Petroleum Development (SPD) we pay significant attention to issues of optimization of the Company budget costs, and thus the issue of maintaining oil production energy efficiency becomes more and more important with each new year.
Within limits of developing information technologies development and application of intellectual management systems become more popular with the main objective to optimize oil production, technical solutions, planning processes and operational expenditures.
In SPD we pay significant attention to "digitalization" of the company operational processes, in this relation in the beginning of 2016 we developed and started a program of daily analysis of production well stock and making decisions on optimization of its operation called "Optimization register" (SPE-191553). This software includes an integrated module of energy efficiency allowing to control and optimize daily energy consumption by electrical submersible pumps (ESP). Best and average practices were developed and implemented – indicators of unit power consumption for artificial lift of fluid by ESP system among other companies in the industry.
This system is integration of well and equipment operating parameters in real time mode and technical information from different databases into one base with automatic check of data correctness and dynamics of ESP energy consumption change. This allows to promptly draw attention of analytical engineer to increase of unit power consumption for the well after replacement of equipment (due to implementation of well interventions or failure of downhole submersible equipment); in the process of degradation of head and flow rate parameters of downhole submersible pumps due to plugging/wear of ESP driven bodies; in case of incompliance of actual well potential with ESP capacity, which is the cause of ESP operation beyond limits of recommended operating envelope, etc. The system provides for an opportunity to make requests for optimization of downhole submersible pump operation to reduce unit power consumption. Requests are automatically directed to performers, the systems tracks status of their implementation.
Automatic detection of high ESP unit power consumption compared to the best and average practices in the industry for specific type of downhole submersible pumps, creation and implementation of requests within limits of optimization of unit power consumption now presents a closed cross-functional cycle of information transfer allowing each participant to have actual data and make a correct decision.
Reliability Assessment of PVT-Properties of Reservoir Fluids on the Basis of a Probabilistic Mixture Model of Student's Distributions
Authors: Volkov Nikita , Andrianova Alla , Serebryakova Darya , Budennyy Semen 
Published: October 2019

Abstract
Substantiation of the component composition and PVT-properties (Pressure, Volume, Temperature) of reservoir fluids is one of the most crucial conditions for increasing the reliability of reserves calculation and efficiency of oil and gas field development.
The main tasks of this article are abnormal samples definition and a prediction of some PVT-properties form other ones. In machine learning this tasks names as the anomaly detection and the regression analysis. To solving this task, the model based mixtures of multidimensional Student's distributions was developed, training of which using variational Bayesian inference.
The developed model was tested on data base containing more than 3200 samples of reservoir fluids. The article compares the proposed method by the quality of the predictions with other machine learning methods, for example random forest, artificial neural networks and SVM regression. Using these models, the quality of PVT-sample parameters prediction was significantly higher than the proposed method of probabilistic mixture of Student's t-distributions.