bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successful Application of Managed Pressure Drilling and Cementing in Naturally Fractured Carbonates Environment of Prohorovskoe Exploration Well
Authors: Krivolapov Dmitry , Soroka Taras , Polyarush Artem , Lobastov Denis , Balalaev Viktor , Valisevich Aleksey , Ivanov Pavel , Pozdnyakov Anton , Smolev Dmitry , Frankov Dmitry 
Published: October 2021

Abstract
This technical paper provides the result of utilizing MPD technology for drilling and cementing a 127 mm production liner withing the Zadonian horizon D3zd in an exploratory well of the Prohorovskoe field. The previous wells drilled with a conventional approach in the field had complicated issues such as circulation losses and well control. It was complexified with high hydrogen disulfide concentration in reservoir oil which was a health hazard to a site personnel. As a result, to eliminate all complications, resources and operational time were needed.
To prevent and eliminate complications in a long wall, core drilling and well completion, managed pressure drilling (MPD) and cementing technology with semi-automatic control system was applied. The project is unique as such complicated jobs with the core drilling and cementing with MPD were executed for the first time in The Komi Republic.
MPD approach allowed to figure out bottomhole safe conditions and maintain ECD within a required pressure window. It is necessary to notice that a part of the section was core drilled.
Knowing the window between pore and fracture pressures safety limits, a run-in-the-hole design with further cementing job was optimized. The execution was done flawlessly without circulation losses and well control issues.
In comparison to a previous well in the Prohorovskoe field, MPD allowed to shorten loss circulated mud volume from 2 2215 m3 to 0 m3 and avoid non-productive time.
Through accomplished goals and lessons learned, new grounds to well owners and well services in a field development stage are broken.
Application of the Advanced Methods to Investigate Incidents and Drilling Engineering Principles to Prevent Critical Wear-Out of Downhole Equipment When Drilling Wells in Chayandinskoye Field
Authors: Abaltusov Nikolay Valerevich , Ryabov Anton Sergeevich , Perunov Artem Evgenevich , Rublev Sergey Sergeevich , Mitrokhin Sergey Aleksandrovich , Mukhachev Igor Yurevich , Fomchenko Roman Gennadevich 
Published: October 2021

Abstract
The pressing challenge is the abnormally rapid wear of well logging equipment and drilling tools when drilling wells in pay zone of Chayandinskoye field. Wear-out of BHA stabilizers within one run makes directional drilling inefficient and results in additional trips to replace equipment. Wear-out of drill pipes results in emergencies risk increase. To prevent such incidents the necessity arises to conduct an unscheduled inspection, reject and replace drilling tools. All these conditions entail increase in drilling time and decline in profitability.
Problem analysis and expert review was made by drilling optimization specialists from DD Contractor jointly with the experts from R&D Center and Operator Company.
This paper discusses how cooperation of the engineers from three companies as well as a particular approach to incident investigation and drilling engineering made it possible to identify the most critical factors, which contribute to a standard BHA wear, to work out measures to prevent similar situations in future and select an alternative BHA.
The gained experience has been successfully disseminated to the other wells in Chayandinskoye field and other fields in Eastern Siberia; and the incident investigation methods and drilling engineering procedures are effectively applied under the other projects.
Specialized ESP Layouts for the Operation of Deep Wells Confined to the Category of Hard-to-Recover Reserves
Authors: Sarapulov Nikolai Pavlovich , Vasin Maxim Valerevich , Palandzhyants Andranik Sedrakovich , Tambovstev Evgeni Alexandrovich , Khabibullin Rinat Alfredovich 
Published: October 2021

Abstract
The article is devoted to the selection of a specialized configuration of submersible equipment to minimize downhole pressure in order to intensify the flow of fluid to the wells of Gazpromneft-Orenburg. The depth of the wells and the design features of the well do not allow sufficient depth of the pumping equipment (top of the perforation interval 3800-4200 m). In addition, the operation of the fund is complicated by abnormally low reservoir pressures (60-120 at), low filtration-capacity properties and high linear pressures of single-standing wells (20-30 at).
To increase the productivity of wells, the ESP layout was used with a two-way engine, two submersible pumps and a shank. The layout is chosen in such a way as to reduce the density of the liquid column under the pump due to the circulation of the liquid by the lower pump. A special feature of the design was the selection of the length and the limit of the descent of the shank, the ratio of performance and pressure of the upper and lower pumps and a number of pre-connected devices as part of the layout.
Pilot tests were conducted at three wells of the Gazpromneft-Orenburg field. After the installation and commissioning work in the process of bringing the wells to the established mode, the features of the ESP that differ from the standard operation, leading to an increase in the period of stable well production, were revealed. According to the results of the tests, an increase in the oil flow rate of an average of 16 tons per day was obtained. The study of the characteristics of a complete installation directly on the test wells allowed us to determine the technical capabilities of the equipment, the volume-flow characteristics of the fluid under the pump and PVT. The aspects of natural separation and free gas content at the inlet of both pumps are studied, which is also a boundary condition for well intensification.
The tests allowed us to assess the technological limit of the layout with two ESP in the conditions of the Gazpromneft-Orenburg field. In contrast to other options for the operation of hard-to-recover wells, the proposed layout has a number of advantages, such as a minimum increase in the cost of construction, simplicity of construction, which ensures high operating time of equipment and low specific energy consumption. Based on the results of testing the pilot installations, a decision was made to replicate this approach in the Company.
New Methodology for Calculating the Impact of High Free Gas Content in the Flow on ESP Characteristics for the West Siberia Fields
Authors: Goridko Kirill Alexandrovich , Khabibullin Rinat Alfredovich , Verbitsky Vladimir Sergeevich , Shabonas Arturas Rimo , Kazakbaeva Guzel 
Published: October 2021

Abstract
One of the most common complications in the operation of wells with electric submersible pumps (ESP) is the presence of free gas in the produced well product. The work considers a model of ESP operation taking into account a large share of free gas in the flow obtained on the basis of bench tests and its applicability for analyzing the operation of real producing wells equipped with ESPs.
Tests of ESP5-50 (118 radial stages) with model gas-liquid mixtures in a wide range of inlet gas volume-flow rate (0-60%), inlet pressure (0.6-2.1 MPa), shaft speed (2400-3600 rpm) with simultaneous pressure measurement along the pump length and direct measuring of power at the shaft by means of motor weights were performed at the oilfield development and operation department. Mathematical model is obtained by means of regression analysis of experimentally received characteristics of ESPs on gas liquid mixtures; a simple engineering method of calculating the degradation of ESPs characteristics by flow, head and power is suggested. The experience of building similar models described in the literature was taken into account. Experimental studies and creation of a mathematical model of ESP were carried out during Kirill Goridko's PhD thesis.
As a result of the research we obtained the degradation dependencies of the pump's delivery and the head of ESP while pumping mixtures of different foam capacity, which simulate the pump operation in low and high watercut wells. The patterns of delivery and head coefficients depending on the zone (left, optimum, right) of ESP characteristic are revealed. The degradation of ESP power during pumping gas liquid mixture is clarified, which allows to calculate more accurately the specific energy consumption of well products lifting. The developed method of recalculation of the pressure and power characteristics of ESPs is implemented in the form of calculation modules designed for engineering calculations in oil production. The proposed tool has been tested on the data of the Western Siberia fields while analyzing the operation of wells with high gas content in the produced product. Calculation modules have been made publicly available.
A new simple engineering method was developed to account for the degradation of the pressure and flow and power characteristics of ESPs for low- and medium-rate wells based on a large number of benchmark studies. Оbtained degradation dependences are programmed in the form of calculation modules, which allows to analyze the operation of a large number of wells on the basis of their technological mode, as well as to propose optimization measures to change the ESP operation at a higher level.
The Choice of the Optimal Strategy for the Use of Solvents of High-Molecular Organic Deposits, Considering their Complex Composition and the Effect on the Oil Dispersion System
Authors: Guskova Irina Alekseevna , Khayarova Dinara Rafaelevna , Abzyapparova Elvira Rafaelevna 
Published: October 2021

Abstract
The long-term practice of operating wells producing oil rich in paraffins and asphaltenes has shown that the optimization of technologies for the removal of solid high-molecular organic deposits (asphaltene-resin-paraffin deposits) in oilfield equipment, lifting pipes and flow lines makes it possible to effectively solve the issues of improving the environmental friendliness and energy efficiency of oil production. The use of composite hydrocarbon solvents is one of the most well-known methods used to remove asphaltene-resin-paraffin deposits. Thus, to date, there is no systemic solution to this issue. This paper is aimed at discussing the provisions that determine the possible prospects for the development of an optimal strategy for the use of solvents for the removal of asphaltene-resin-paraffin deposits.
Interfacial Tension Measurements at Reservoir Conditions Using X-Ray Imaging
Authors: Pletneva Vera , Korobkov Dmitry , Kornilov Anton , Safonov Ilia , Yakimchuk Ivan , Stukan Mikhail 
Published: October 2021

Abstract
Interfacial tension (IFT) is one of the key parameters governing multiphase flow in reservoir. One of standard IFT measurement techniques is pendant drop shape analysis, which includes an acquisition of the drop snapshots in visible light. Hence, the method is limited by optical transparency of an external fluid. Here we present a new approach, which is free from this limitation. It uses X-rays as an illumination source and provides a number of advantages and additional opportunities in the study of fluid interface behavior. Proposed method includes a drop generation inside a uniquely designed X-ray transparent cell for high pressure and temperature (HPHT) measurements placed inside an X-ray scanner and imaging of its evolution with time till equilibrium state. Since X-ray images significantly differ from the classical optical ones, a novel algorithm was developed for accurate drop shape detection and further mathematical processing for IFT value calculation. As a result, an IFT value evolution curve for a pair of fluids is obtained. Depending on relative densities of the fluids, different experimental schemes can be implemented: pendant or rising drop.
The method was validated on various neat fluids with well-known IFT values and then was successfully applied for different real fluids systems. This work demonstrates the unique laboratory studies carried out on different liquid-fluid systems showing that the developed methodology works well at elevated pressure and temperature conditions.
The developed method unlocks the possibility for an appropriate IFT measurements in surfactant-rich oil-water systems as well as in systems near the phase transition such as gas-condensates at a wide range of thermobaric reservoir conditions and increases feasibility of HPHT measurements due to simplification of the measuring system design.
Experience of Application of Different Multiphase Metering Technologies for Cold Production and High Viscosity Oil Systems
Authors: Tonkonog Mikhail Igorevich , Kaipov Yermek Talgatovich , Pruglo Dmitry Sergeevich 
Published: October 2021

Abstract
Production monitoring is essential not only for fiscal applications, but also for production optimization and efficient reservoir management. So, production measurements must be both accurate and frequent enough, revealing a consistent trend of well operating parameters. This is especially important for reservoirs of complex geology, like oil rim reservoirs in poorly consolidated sandstone formations with presence of aquifer and gas cap drive. Production monitoring can be implemented with different technologies, accuracy of monitoring is however affected by different factors like gas content, viscosity and temperature of produced fluids. Paper presents pragmatic approach and analysis of applicability of different measurement technologies: compact two-phase separator and two different multiphase metering technologies applied at oil wells of Tazovskoye field operated by LLC "Meretoyakhaneftegaz", which production conditions are very challenging due to high gas volume fraction of the produced fluid, high viscosities and low temperatures.
The Interpretation Technique of Rate Transient Analysis Data in Fractured Horizontal Wells
Authors: Urazov Ruslan Rubikovich , Davletbaev Alfred Yadgarovich , Sinitskiy Alexey Igorevich , Zarafutdinov Ilnur Anifovich , Nuriev Artur Khamitovich , Sarapulova Veronika Vladimirovna , Nosova Oxana Evgenievna 
Published: October 2021

Abstract
This research presents a modified approach to the data interpretation of Rate Transient Analysis (RTA) in hydraulically fractured horizontal well. The results of testing of data interpretation technique taking account of the flow allocation in the borehole according to the well logging and to the injection tests outcomes while carrying out hydraulic fracturing are given. In the course of the interpretation of the field data the parameters of each fracture of hydraulic fracturing were selected with control for results of well logging (WL) by defining the fluid influx in the borehole.
The Use of Chromate Desorption Systems to Optimize the Position of the Wells Relative to the Contact Boundaries During the Development of Oil Rim Fields
Authors: Lutoev Pavel , Kuznetsov Dmitry , Nikishin Igor , Efimov Evgeny , Minakhmetov Radik , Platonov Igor , Nukhaev Marat , Kabanov Vasilii , Zaitsev Alexsandr 
Published: October 2021

Abstract
This paper presents a novel technology for identifying the inflow profile during the oil rim development using chromate desorption systems that makes it possible to solve one of the critical tasks related to long horizontal and multi-bottom-hole wells—optimizing the position of well relative to the contact boundaries to prevent early water breakthroughs and gas outs.
A New Approach to Simulation of Wax Precipitation During Cold Water Injection in Carbonate Reservoir of Kharyaga Oilfield
Authors: Trushin Yuri Mikhailovich , Aleshchenko Anton Sergeevich , Zoshchenko Oleg Nikolaevich , Arsamakov Mark Suleimanovich , Tkachev Ivan Vasilevich , Kruglov Dmitry Sergeevich 
Published: October 2021

Abstract
The paper describes a methodology for assessing the impact of wax deposition in reservoir oil during cold water injection into heterogeneous carbonate reservoir D3-III of the Kharyaga field. The main goal is to determine the optimal amount of hot water that must be injected before switching to cold water without affecting the field development. The paper presents the results of laboratory studies to determine the thermophysical properties of oil, samples of net reservoir and non-reservoir rock, as well as the results of laboratory studies to determine the conditions and nature of wax deposition in oil when the temperature and pressure conditions change. Calculations were carried out to describe the physical model of oil displacement by water of various temperatures. A series of synthetic sector model runs was performed, which includes the average properties of the selected reservoir and the results of laboratory studies in order to determine the effect of cold water injection on the development performance.
Technological Features of Associated Petroleum Gas Miscible Injection MGI in Order to Increase Oil Recovery at a Remote Group of Fields in Western Siberia
Authors: Vershinin Sergey Anatolevich , Blyablyas Alexander Nikolaevich , Golovanov Dmitriy Aleksandrovich , Penigin Artem Vitalievich , Glavnov Nikolay Grigorievich 
Published: October 2021

Abstract
The problem of associated petroleum gas utilization is especially urgent for fields located far from infrastructure facilities for raw gas transportation and treatment. For such fields, alternative methods of gas utilization, especially gas re-injection, are becoming relevant. The re-injection options include: injection into underground reservoir for storage (if there are reservoirs suitable for injection near the field), injection into a gas cap, if any, or injection into a productive reservoir. The latter method allows, along with solving the problem of gas disposal, to increase oil recovery. This study describes an example of miscible gas injection into the reservoir at the Chatylkinskoye field, the infrastructure assumptions which make this option a better one versus a selling option, and the features of a gas treatment and injection process.
Diagnostic Plots for Production Decline During the Transition of Oil Field Development From Depletion to Water Injection
Authors: Syrtlanov Vil , Golovatskiy Yury , Ishimov Ivan 
Published: October 2021

Abstract
In this paper the simplified way is proposed for predicting the dynamics of liquid production and estimating the parameters of the oil reservoir using diagnostic curves, which are a generalization of analytical approaches, partially compared with the results of calculations on 3D simulation models and with actual well production data.
The Use of Tracer Technologies for Well Monitoring with Multi-Stage Hydraulic Fracturing on Bolshetirskoye Oil Field
Authors: Krasnov Ivan , Butorin Oleg , Sabanchin Igor , Kim Vasiliy , Zimin Sergey , Pshenichniy Alexander , Toporov Alexey , Ivanoshchuk Igor , Valeev Ramil , Galimzyanov Artem , Naydenskiy Konstantin 
Published: October 2021

Abstract
With the development of drilling and well completion technologies, multi-staged hydraulic fracturing (MSF) in horizontal wells has established itself as one of the most effective methods for stimulating production in fields with low permeability properties. In Eastern Siberia, this technology is at the pilot project stage. For example, at the Bolshetirskoye field, these works are being carried out to enhance the productivity of horizontal wells by increasing the connectivity of productive layers in a low- and medium- permeable porous-cavernous reservoir.
However, different challenges like high permeability heterogeneity and the presence of H2S corrosive gases setting a bar higher for the requirement of the well construction design and well monitoring to achieve the maximum oil recovery factor. At the same time, well and reservoir surveillance of different parameters, which may impact on the efficiency of multi-stage hydraulic fracturing and oil contribution from each hydraulic fracture, remains a challenging and urgent task today.
This article discusses the experience of using tracer technology for well monitoring with multi-stage hydraulic fracturing to obtain information on the productivity of each hydraulic fracture separately.
Geochemical Monitoring of Formation Fluids for Reservoir Management Considering Complicating Factors in Mature Oilfields
Authors: Shipaeva Mariya Sergeevna , Nurgaliev Danis Karlovich , Zaikin Artem Aleksandrivich , Sudakov Vladislav Anatolevich , Shakirov Artur Albertovich , Abuzarovich Lutfullin Azat , Ganiev Bulat Galievich 
Published: October 2021

Abstract
At the present stage of the hydrocarbon production process, most of the unique and largest fields in the world are at a late stage of development. Despite the active development and policy of a decarbonised economy, the demand for liquid and gaseous hydrocarbons remains high, while of inevitably growing the number of mature fields. The Volga-Ural oil and gas province today is an old oil and gas producing region, most of the fields have already entered the final stage of development. However, through the introduction and development of new technologies for oil extraction, monitoring of production and localization of reserves, the life of the fields can be extended. One of these technologies is geochemical monitoring of well production. Its goal is to optimize the development of mature fields on the basis of promptly obtained information about the state of the wells using geochemical studies of the formation fluid, allowing timely implementation of the necessary measures. Geochemical studies allow identifying the source of fluid entering the well, determining a violation in the wellbore structure, checking the tightness of downhole equipment for separate operation, and performing an area analysis of the area development efficiency. This type of research is relevant both in giant fields with a large stock of production wells, often characterized from a geological point of view by multilayer structure, with technological complexity, packing, wear of equipment and strings, in some cases the impossibility of running gauge for research, and in fields with low depletion. The possibilities of geochemistry for solving local operational problems in wells are shown. Several hydrogeological complexes have been studied, the change in the properties of the produced water during the development process is described. The concepts of the geochemical conditions in the hydrocarbon deposits that existed earlier are changing due to the development of these objects as a dynamic system, continuous injection of different types of water into the reservoir, the use of enhanced oil recovery methods and other technogenic impact associated with the development of reserves. The digital revolution and the modern development of the industry marked the beginning of the creation of the Digital Atlas of Groundwater, the development of specialized algorithms that allow processing large amounts of data.