bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Technologies Application to Solve Practical Challenges in Exploration and Development of HC in the Russian Sector Of Caspian Sea
Authors: Deliya S. V. , Valisevich A. Y. , Abetov A. E. , Bulybenko K. A. , Khusainov R. F. 
Published: October 2013

Abstract
Hydrocarbon deposits in the Russian sector of the Caspian Sea are characterized by a considerable variety of traps in a
wide stratigraphic range, substantial lateral substitution of lithological and reservoir properties, variation of structural and morphological characteristic, fluid saturation and hydrocarbons phase composition. Exploration and development of these fields are complicated by the fact that they are located in challenging ice conditions zone (in wintertime), in the region with the strictest environmental requirements where LLC "LUKOIL" is the pioneer in offshore projects.
To overcome successfully geological, technical and climatic difficulties LLC "LUKOIL – Nizhnevolzhskneft" supported technically by "Schlumberger" applied a number of unique technological solutions concerning drilling muds, stem assemblies, geo-steering and geomechanics, wireline and mud logging, hydraulic fracturing, high-performance drilling bits, as well as intelligent completions, application of up-to-date high-performance tools, advanced software, methods of processing and interpretation of geological and geophysical data. Overview and analyze these solutions is the objective of this article.
Availability of theoretical and practical resources while implementing the project, mutually-beneficial cooperation of all interested parties together with innovative decisions supported by corporate management became a key point of success in fulfillment of capital-intensive projects by LLC "LUKOIL Nizhnevolzhskneft" in the Russian sector of the Caspian Sea.
It is obvious that there are quite serious reasons for further application of new technologies according to proven algorithm: problem statement-finding solutions – planning- implementation- analysis of obtained results, recommendations working-out, and establishment of close partnership relations between Project operator and multifunctional engineering company.
Further improvement of drilling technologies, optimization of hydrocarbon production, provision of the necessary facilities for field development, adaptation of DOF concept, geological monitoring while well drilling, application of new scientifically dereived, technologies and advanced logging tools without chemical sources, drilling mud and bits, using modeling and prediction in real time are considered as prospective conceptual ways.
It can be said with confidence that fulfillment of the above mentioned measures and already implemented solutions at the Northern Caspian region will change dramatically approaches to hydrocarbon deposits development, and will help to explore hydrocarbon potential to the full extent in the Russian sector of the Caspian Sea.
Methods and Devices for Determination of Gas-Kick Parameters and Prevention of Well Explosion
Authors: Tseytlin Simon 
Published: October 2013

Abstract
The presented acoustic methods and devices are intended for early detection and determining parameters of the gaseous packet (gas kick) rising in the annulus of the well during a gas blowout. The action of the tool is based on the comparison of pressure pulses generated in the mud by the mud pump using dynamic pressure sensors located in the annulus above the blowout preventer and in the high-pressure line. When the output signal decreases to the pre-specified level corresponding to the danger of blowout, the drilling is stopped and a pressure pulse is generated in the annulus; the location, velocity, size and arrival time of the gaseous packet is determined using the arrival time of the reflected signals. The information obtained this way is used for making a decision whether to resume drilling or to take measures to suppress gas entry into the borehole. The tool also makes it possible to detect free-phase highly dissolved gas entering the annulus at the saturation pressure; such gas is especially dangerous when formations saturated with hydrogen sulfide and carbon dioxide are penetrated. The tool is recommended to be incorporated in well-logging units, MWD systems and also as a stand-alone tool among the other instruments used at the well site. The tool makes it possible not only to ensure safety during drilling, but also to facilitate the introduction of the state-of-the-art drilling technologies based on reduction of the bottom-hole differential pressure.
Comparative Evaluation of a Heterogeneous Light Oil Reservoir Performance: Thermal IOR Simulation, Bitumen Extraction, and Associated Geomechanical Deformation
Authors: Al-Mudhafer Wathiq J. , Zein Al-Abideen Mohammed J. 
Published: October 2013

Abstract
A Steamflooding study has been doing to extract the bitumen and improve oil recovery in a heterogeneous light oil reservoir of South Rumaila oil field. It has been investigated also that Steamflooding is an effective way to handle the formation’s heterogeneity by decrease the degree of fluid spread and distortion. It has been considered the design of experiments methodology and streamlines-based simulation to study the most sensitive factors affecting the cumulative oil production response and also to determine the optimal future reservoir performance. This paper is an extension work of the papers (SPE 165345 & SPE 165935) to evaluate the Geomechanical deformation associated with the production processes through steamflooding and water injection scenarios. The reservoir under study is a sandstone formation in South Rumaila oil field located in Iraq. This field, with a 59-year production history, has 40 production wells and is surrounded by an infinite active edge water aquifer from the east and the west flanks. Because of some discontinuous series of bitumen at the east flank, the strength of east flank is much effective less than the west one. In this study, a comparative thermodynamic simulation study has been conducted to show the feasibility of Steamflooding to extract the bitumen and improve oil recovery and to determine the optimal future development scenario in addition to locally estimating the associated reservoir deformation due to steamflooding processes and the base case of water injection.
In this paper, the black oil & thermodynamic reservoir simulator have been used to evaluate the reservoir performance through the base case and steamflooding scenarios, respectively. Later, full factorial design and streamlines-based simulation have been conducted to figure out the most factors affecting the response (recovery factor) through Steamflooding with distinct levels. The factors are steam injection rate, quality, temperature, and number of steam injectors.
Finally, as the oil produced for long time, the pore pressure would decrease with increasing the effective stress leading to reservoir compaction and vertical surface subsidence. Therefore, the expedition in production due to IOR/EOR methods should enhance the reservoir subsidence leading to serious problems in surface facilities setting. Therefore, the two models have been adopted to estimate the reservoir subsidence through steamflooding and base case, respectively.
By the end of 1 Feb. 2022, the results demonstrated that reservoir subsidence at the base case without steamflooding reached to approximately 10 ft as average at the crest of the reservoir. However, the reservoir subsidence after considering the steamflooding to the same date is more than 12 ft at the reservoir crest. However, The current subsidence for this reservoir in the current time after 59 years of predict is approximately two ft. at the crest.
Application of 3S-Technology for the Natural Gas Processing under Arctic Conditions
Authors: Imaev Salavat Z. , Bagirov Lev A. , Voytenkov Evgeny V. 
Published: October 2013

Abstract
SuperSonic gas Separation technology (3S-technology) was designed to prepare the gas for transportation and to extract different fractions from gas, such as hydrocarbon condensate, propane-butane and ethane. The technology is based on cooling of swirling gas in supersonic Laval nozzle. Due to the implementation of high speed in the nozzle, the temperature of gas can be reduced by 70°C and more, thus ensure conditions needed for condensation and separation of heavy fractions contained in gas. A device, realizes this process, is called "3S-separator". It comprises a stationary swirl body, a supersonic nozzle and a diffuser with selection of condensed fluid.
It has been proved that usage of 3S-separators instead of Joule-Thomson valves makes it possible to ensure higher operating efficiency of associated gas processing devices in any parameters. And it can reduce dew points of water and hydrocarbons of a tank gas and increase the amount of gas recoverable from unstable condensate.
3S-separators make it possible to extract target components from natural gas in wide gas input pressure range from 1.0 MPa to 16 MPa. To ensure the optimum gas temperature at 3S-separators inlet recuperative heat exchangers should be used.
At present 3S-technology is successfully used by several industrial plants in Russia ("Rosneft" JSC, "Gazprom" JSC) and abroad (PetroChina Company Ltd.). The use of this technology in subsea processing plants will enable to carry out gas conditioning in accord with sales gas qualifying standards. Thus, as opposed to currently existing gas cooling technologies, based on using of expansion turbines and refrigerator sets, 3S-technology makes it possible to ensure high equipment reliability and enables to install equipment on the seabed. The more promising area – is use of 3S-technology in projects of getting a high pressure (100 and more atmospheres) sales gas. It is impossible to use conventional gas cooling technologies, because of supercritical conditions of natural gas, under which gas additives condensation is not possible at any temperatures. By ensuring high-speed gas flows in supersonic nozzles, there could be a condensation and separation of natural gas target fractions in 3S-separators, even in a high gas pressure conditions.
Engineering Approach to Solving Problems of Flooding of Low-Permeability Compartmentalized Reservoirs
Authors: Yudin Evgeniy , Lubnin Alexander 
Published: October 2013

Abstract
In this paper authors propose an approach to the identification and predicting the waterflooding efficiency. The method is based on the simplified analytical model of the well performance in the waterflood pattern. This model allows us to calculate well productivity in waterflood pattern in all regimes (transient, pseudo-steady, steady) and carry out various practical calculations to determine the efficiency of reservoir-pressure maintenance. The paper presents examples of the described approach application.
Complex Modeling and Efficiency Evaluation of Free Gas Breakthrough Isolation Efficiency with Foaming Systems in Conditions of Oil Rim Drainage at Caspian Sea Shelf
Authors: Mosesyan A. A. , Simakov Y. O. 
Published: October 2013

SUMMARY
This paper is a description of the main stages of research work for determining the cause of high gas-oil ratio on the Yu. Korchagin field, as well as developing recommendations for gas breakthrough isolation.
As the main tool to determine the causes of premature gas breakthrough and to assess the effectiveness of isolations, the reservoir model (hereinafter RM) was used. To obtain initial data to specify the actual model, preliminary work was carried out to analyze and interpret the entire spectrum of studies conducted in the field. Well tests allowed to determine the energy state and filtration-capacity characteristics of the well bottom-hole zones; downhole logging data – refine gas influx profile through the perforation intervals; laboratory studies of fluids and cores were used to create EOS fluid model.
All the results obtained were included into the RM. Then the RM was history matched. During the matching and sensitivity analysis of the model to gas-oil ratio, all sources of gas breakthrough in wells were distinguished. Growth of the gas-oil ratio was largely the result of breakthrough from overlying horizon and gas cap cone formation. To a lesser degree the high gas-oil ratio values caused by oil degassing process in a wellbore.
The main recommendation to reduce gas inflow in the upper perforation intervals was to inject a water soluble surfactant (foam). Foam obtained at formation conditions reduces gas mobility and surface tension at the phase interface, thus allowing to achieve the gas influx blocking.
Lack of domestic experience for such operations was compensated by the experience from the Norwegian continental shelf. Projects at Snorre and Oseberg provided data about specific surfactants, their properties and behavior in the reservoir. These data allowed to focus on selecting a specific surfactant and include its PVT properties into the model. Since the conditions in the Caspian Sea shelf are distinct from the North Sea, additional laboratory studies at "LUKOIL-VolgogradNIPImorneft" were conducted on field core samples for oil displacement in presence of selected surfactant. The data obtained was incorporated into the foam model.
History matched RM allowed to make justified estimation of different options for foam treatment at each well. The obtained results allowed to select optimal scenario for each well, specific recommendations were formulated according to it.
The obtained results allowed to the conclude on effectiveness of integrated approach to modeling, where the RM with all relevant information about the field plays a crucial role at every work stage – from determining the causes to making recommendations to prevent them.
According to the research results, LUKOIL-Nizhnevolzhskneft approved a foam treatment pilot program in one of the wells of Yu. Korchagin field.
Justifying the Optimal Length of Horizontal Wells by the Results of Multiple Flow Simulation Runs
Authors: Levanov A. N. , Silvestrov S. I. , Ustyugova E. V. , Pospelova T. A. 
Published: October 2013

Abstract
A case study of one of the reservoirs of X Field, Greenfield (Russia, Krasnoyarsk Territory, Rosneft OC) considered the approaches applied to determine the optimal length of a horizontal well (HW) on a flow simulation model. In particular, the flow simulation model includes the results of well logging – production log in comparison with permeability, indicating a mismatch between volumes of interval fluid inflow into the well and permeability values of the interval.
The differences of the results of the work previously performed involve the fact that a standard procedure to determine the NPV (net present value) of the project was applied, which is included into field development plans (FDP), supplemented by indicators that take into account higher well drilling costs with increasing of a horizontal part and changes in the liquid inflow intensity per unit length of a horizontal wellbore. The outcome of the study was the creation of a method to determine the optimal length of a HW using flow simulation.
The value of the work involves a more confident prediction of oil recovery levels for horizontal wells and, as a result, the amounts of investment required in case of low reservoir knowledge.
Experience of Using Water Cut Meters at Samotlor and Verkhnechonskoe Fields
Authors: Klimentyev A. G. , Dubovitskiy S. A. , Sharapov E. A. , Shevchenko S. D. , Zubakin A. A. , Minchenko D. A. , Otylov E. A. , Muravyev A. V. 
Published: October 2013

Summary
As the operation process moves on to the advanced stages of field development, the increase in water cut is observed; that makes it necessary to apply technologies to reduce water onset. Timely prevention of problems associated with water onset is possible due to equipment ensuring continuous monitoring and high accuracy of measured values. Modern water-cut meters based on near-infrared absorption spectroscopy can distinguish oil, water, natural gas, and gas-hydrate inhibitors such as methanol.
Field testing of water-cut meters was performed by Samotlorneftegaz OJSC and Verkhnechonskneftegaz OJSC.
Water-cut metes were mounted into Group Measuring Stations (GMS); the readings were displayed on the upper level of Automatic Process Control system of the company what enabled real time water-cut monitoring. Measurement accuracy was evaluated by means of comparative testing with the laboratory testing results of oil well fluid samples. To ensure stable accurate performance of the water-cut meter within the rated tolerances and ability to compare the measured values with the laboratory sample test results, it is important to maintain turbulent flow conditions: vertical velocity of min. 0.6 m/s, and horizontal velocity of 1.2 m/s. It will ensure adequate mixing. Besides, other methodological aspects are important, such as mutual alignment of the water-cut meter and sampling port, sampling frequency, mixer availability, group measuring station operating mode, etc.
The economic effect of high-quality dynamic water-cut measurements (taking into account synergetic effect of other technologies) is achieved due to various factors: fewer inefficient well interventions; improving of decision-making; timely prevention of water onset; reduction of operational costs for manual sampling and laboratory analysis; incremental oil production by eliminating of premature well conversion to non-commercial stock due to poor quality measurements, and improved safety.
Non-Regular Well Placement Optimization
Authors: Ermolaev Alexander , Kuvichko Alexander 
Published: October 2013

Abstract
This paper covers few mathematical aspects of well location and related optimization problems. This problem is of great importance and covered by many authors. Some related studies are described in the paper. Current study formulates these problems in terms or integer programming. Optimal solutions formulate initial sets of cases and improve the efficiency of oil and gas recovery. Considered integer programming problems are extremely large-scale problems. The matrix structure, the number of feasible solutions, etc. have been taken into account. A new fast algorithm for the generalized non-square assignment (transportation) problem has been designed. It is reasonable to use the approach studied in this paper to design a set of appropriate initial cases for the small fields or fields with a complex geology. Presented workflow finds optimal well positions for a field or its part. A Brugge field has been taken as a test case. An improvement of production and NPV achieved the comparison between an initial and an optimal case presented.
Seismic Challenges and Structural Solutions on the Berkut Platform
Authors: Slatnick S. C. , Fenz D. M. , Sheppard R. E. , Turner J. W. 
Published: October 2013

Abstract
This paper describes the methodology and technical solutions employed to address earthquake loading challenges on the Berkut topsides, including design and operational considerations. The Berkut platform is part of the Sakhalin-I development in offshore Russia, which is located in an area of high seismicity. Offshore platforms in the region require highly specialized designs to balance the competing requirements resulting from earthquake, wave and ice loading. Design strategies used in the region to protect structures from earthquakes include a tuned mass damper to protect the drilling derrick on the Orlan platform and Friction Pendulum seismic isolation on the Lunskoye-A and Piltun-Astokhskoye-B platforms.
The Berkut structure consists of a four-shaft gravity based structure (GBS) with a topsides operating weight of approximately 50,000 tonnes. Seismic isolation devices called Friction Pendulum Bearings (FPBs) are placed between the GBS shafts and the topsides to reduce horizontal load transfer and accelerations. A performance-based design approach was developed to derive load and resistance factors providing a specified probability of non-performance (2% in 50 years with a minimum 90% level of confidence). This approach, which can be applied to a broad range of extreme environmental design criteria, enabled the seismic design for Berkut to be completed with a more consistent level of reliability than would have been achieved using traditional methods. Seismic analyses were carried out using nonlinear time history analyses of a fully coupled analytical model containing topsides, GBS and soil. This was complemented by finite element analysis for local design.
A seismic event of smaller magnitude than the design event can impact production unless Operations personnel can confirm that no safety-critical components have been compromised by earthquake loading. A custom structural monitoring system has been configured to monitor accelerations and FPB displacements; and an earthquake-response strategy has been implemented to enable Operations personnel to make prudent decisions following an event.
Assessment of geomechanical concept for natural and manmade fractures in bazhenov and tyumenskoe formations using an example of study in Em-Yoga field Krasnoleninsky arch West Siberia
Authors: Platunov A.. , Martynov M.. , Nikolaev M.. , Leskin F.. , Davidenko I.. 
Published: October 2013

Abstract
This paper is based on study of formations in Bazhenov and Tyumenskoe horizons of Em-Yoga field Krasnoleninsky arch West Siberia with the aim of defining the geomechanical concepts of studied area. Hydrocarbon production from Bazhenov and Tyumenskoe formations in West Siberia is actually established through number of pilot wells with production testing. Economic profitability of producing wells depends on the efficiency of hydraulic fracturing in cases where the technology is predefined by reservoir development project. This article describes the principles and prerequisites of hydraulic fracturing mechanics under geomechanical conditions of the studied rocks.
Tyumenskoe and Bazhenov formations are dated to Upper and Middle Jurassic geological time. Geological depositional environment and posterior transformations in time have created specific conditions for rock geomechanics. Rock mechanics in studied formations practically predetermines the concept of how rock is fractured. This work presumes basis for typification and description of fractures occurred naturally and created as a result of hydraulic fracturing and how those interfere with each other.
This work is stand on the accumulated results of the ongoing study and actual data from producing wells in Em-Yoga field Krasnoleninsky arch West Siberia. The Jurassic rocks studied in this article are stratigraphically divided into formations of Tyumenskoe, Abalak and Bazhenov horizons. Enacted stratigraphic cross-sectional classification describes the formations of Tyumenskoe horizon as porous rock, Abalak horizon as cavernous-porous naturally fractured and Bazhenov as naturally fractured and micro-porous types of rock.
Extended Reach Exploratory well Successfully Drilled on D-41 Structure of Baltic Sea Shelf (Russian Sector)
Authors: Andrianov Vyacheslav , Solovyanchik Vasily , Aleshkov Valery , Akhmetov Marat , Kostin Sergey , Mazaev Konstantin 
Published: October 2013

Abstract
This paper describes some of the major issues around drilling world class ERD well in the Baltic Sea by a team of industry professionals from Lukoil, Schlumberger and Eurasia Drilling Company (BKE). The ultimate goal of the well construction organization was to deliver quality well under budget and within schedule with zero environmental impact.
A challenging well was successfully drilled to explore Cambrian production zone in D-41 structure. Key contributing factors to this success were: –solid preliminary analysis,–understanding of well bore stability by real time geomechanical modeling,–comprehensive directional analysis,–revised casing design,–application of latest drilling technologies,–creation of multi-discipline team with common goals.