bluuebunny/crossref_metadata_2025_split huggingface dataset:
First Russian Underground Oil Pipeline with "Skin-Effect" to Transport Jellying Oil
Authors: Grishagin A. V. , Kologreeva T. I. , Smirnov A. V. , Shashel V. A. , Vakulenko S. N. , Savinova I. V. , Kamashev R. A. 
Published: October 2012

Abstract
Following the problems related to transportation of high paraffine content oil at one of the fields of OAO "Samataneftegas" we have investigated rheological properties of well products with abnormally high temperature of solidification (+36°C).
The essential dependence of viscosity vs temperature in the interval of velocity gradients from 20 to 300 sec-1 was determined: at 20°C - from 2799 up to 356 MPa*sec; at 30°C - from 177 up to 67.8 MPa*sec; at 40°C – 14.1 MPa*sec (Newton); 50°C – 7.8 MPa*sec (Newton).
Thus it was revealed, what at temperatures lower than 25°C it is possible to face the issue of paraffin fraction depositions into a solid phase, as well as the jellying of the product. This has been proved by numerous complete shutdowns of 159 x 6 mm operating pipeline and significant expenses for its rehabilitation.
The results of rheological tests have predetermined the search of means that allow resolving this problem. The only acceptable strategy in this case (in view of connecting new licensed areas) was the one to use the system of pipeline heating.
Such systems provide maintaining the temperature of transported product by compensating the heat losses from pipeline surface to the environment.
The problem is in the following, that 210 x 6 mm oil pipeline (having the overall length of 13.5 km of which 12.8 km should be heated) planned for construction, should be laid in a trench at the depth of not less than 1.6 m to the upper surface of the pipe.
The designing of such an object and its commissioning was done in Russia for the first time. To heat the underground sections of the oil pipeline they have used SKIN-system based on "skin-effect" principle. The construction was carried out between December 2010 and October 2011. Pipeline was constructed between December 2010 and June 2011; installation of "skin-effect" system was done between June 2011 and October 2011.
Oil pipeline with skin-system (mainitaining the temperature of 40°C) was commissioned on 11.14.2011 and tested in extremely cold period of the year. Till now it has transported around 75 thousand cubic meters of well products (860 m3/day in average).
Using aerospace information for monitoring green fields in the Russian Arctic region
Authors: Sevastyanova K. K. , Shmakov V. V. , Nekhaev S. A. , Konygin A. E. , Stolbov S. A. 
Published: October 2012

Abstract
The article presents the concept of building and developing a corporate system of Earth remote sensing (ERS). Remote sensing from space has a significant advantage over the traditional information support technologies for existing business processes in most russian industries, including oil and gas industry, by reasons of high efficiency, productivity, operability and low cost materials.
Experimental Studies of Oil Recovery After Alkali-Surfactant-Polymer (ASP) Flooding with West Salym Cores
Authors: Skripkin A. G. , Kuznetsov I. A. , Volokitin Ya. E. , Chmuzh I. V. 
Published: October 2012

Abstract
Chemical EOR project in Salym Petroleum Development (SPD) aims to increase oil recovery factor by applying a mixture of alkali, surfactants and polymer (ASP). In West Salym field it is expected to gain increase in oil recovery of 10–20%. A successful ASP pilot was conducted by Shell in 1989 in several wells of White Castle field, LA, where 38% of oil left after water-flood was recovered by ASP flooding.
ASP method was first developed in early 80s in Shell, in Bellaire Research center, Houston, as a result of field testing of different chemical methods. Surfactant in the mixture reduces interfacial tension between oil and water, which leads to mobilization of resudual oil in porous medium of the rock. For efficient mobilization of oil the value of interfacial tension should be lowered down to extra-low values of 10-3 mN/m. Alkali is added in order to reduce adsorption of surfactant into the formation, which helps to bring down consumption of expensive surfactants. Polymer increases viscosity of the mixture, which helps to stabilize flow, improve sweep and displace viscous emulsion created in the formation.
Several companies are involved in the SPD project: surfactant selection is done by research department of Shell, core experiments are conducted in the Laboratory of Reservoir Physics in JSC TomskNIPIneft, Salym Petroleum Development N.V. manages and coordinates the project. Recently GazpromNeft Research Center joined the work on surfactant selection. The objectives of the experiments conducted in JSC TomskNIPIneft were: Determination of the optimal salt concentration for creation of the maximum volume of micro-emulsion in the mixture of oil and ASP cocktail based on phase behavior tests.Modeling of reservoir conditions of West Salym field and expected technological operations during injection of ASP solution in the core flood experiments.Determination of residual oil after ASP flood and its distribution along core column at various volumes of ASP slug, various concentrations of salt and alkali, and various polymer viscosity.
Causes of Decreased Condensate Recovery from Low-Permeable Formations and Ways to Increase it
Authors: Shandrygin A. N. , Yushkov A. Yu. , Glumov D. N. 
Published: October 2012

Abstract
The paper investigates the processes of condensate recovery from low-permeable formations during depletion-driven development of gas-condensate deposits. The studies were based on simulating multi-component flow of various gas-condensate mixtures in reservoirs with a large range of permeabilities. As a result, the key causes of decreased condensate recovery from low-permeable formations compared to "regular" reservoirs have been established. It was shown that for low-permeable formations, due to large pressure drawdown cones, the additional condensation of C5+ components because of an "non equilibrium" effect is possible, where the flowing gas phase is out of equilibrium to the retrograde condensate.
The main technological factors influencing the condensate recovery from low-permeable formations were identified, as well as possible ways to increase condensate recovery.
Approaches for Estimating Carbonate Fractured Reservoir Property Cutoffs
Authors: Kolganov V. , Kovaleva G. 
Published: October 2012

Abstract
In Russia, since 1972, core correlation relationship between connate water saturation cw and porosity αwc=f(m) is used for porosity cutoff estimation based on methods which have been generated to find property cutoffs: 1)method of effective porosity me=m(1-αwc)2)method of dynamic porosity md=m(1-αwc-αor), where αwc and αor–connate water and residual oil saturation
Estimation method of property cutoffs is as follows: plot petrophysical correlation relationship me=f(m) and md=f(m), which are usual as line functions with high correlation coefficient. Find graphically or analytically cross points of porosity axis and functions me=f(m) and md =f(m). Sections on this axis intercepted with points me=0 and md=0 are accepted numerically as porosity cutoffs.
Judging by foreign publications, correlation relationships me=f(m) and md=f(m) are used only in domestic practice of estimating hydrocarbon reserves and thus this method can be considered as Russian know-how.
Oil reserves estimated by the method me are in-place reserves, by the method md – producible reserves. Both options of correlation methods estimate matrix cutoffs for carbonate fractured reservoirs.
Memory pulsed neutron-neutron logging
Authors: Arbuzov A. A. , Alekhin A. P. , Bochkarev V. V. , Minakhmetova R. N. , Chukhutin D. V. , Zakirov A. N. 
Published: October 2012

Abstract
This paper describes the MINK tool which is based on pulsed neutron-neutron (PNN) logging technology, its key principles and differences from other logging and data interpretation methods, and illustrates its applications to estimating oil saturation in wells.
The principal feature of the MINK tool is its data recording technique in which all neutron-count decays are saved to memory and processed separately. In conventional PNN logging, 100 decays are initially accumulated and then averaged before processing, which results in information loss.
Theoretical considerations and available experimental data have indicated that the probability distribution of neutrons is governed by Poisson's law [1] and allows the use of the maximum likelihood method (MLM) for experimental data fitting [2] with a substantial advantage over the conventional least-square method (LSM). This was particularly important for reservoir characterisation, as the rock's response is mainly recorded at late times. Neutron count rates at late times are small, and the least square method becomes a hit-and-miss technique. The authors have developed algorithms and software for the efficient and reliable determination of single- and double-exponential approximation parameters using the maximum likelihood method.
The processing of data from three selected wells has shown that Sigma profiles determined by the least square method are noisier than those determined by the maximum likelihood method. Moreover, some thin reservoir units were not seen in Sigma profiles obtained by the least square method, in contrast to those obtained by the maximum likelihood method.
Statistical modelling has been performed to validate the developed algorithms. Decays with experimentally determined decay times and Poisson's distribution of neutron count decays have been generated. Modelling data processing has shown that the maximum likelihood method provides 1.7 to 2 times higher accuracy than the least square method under equal conditions or 3 to 4 times smaller data collection volumes.
The MINK technology is expected to determine the oil content in dense reservoirs and low-salinity wellbore fluids.
Refinement of a Geological Reservoir Model by Detailed Correlation
Authors: Mubarakova A. , Sudakov V. , Sidorov S. 
Published: October 2012

Abstract
It is very important to understand sedimentation in detail, both from the aspect of geological or petrophysical modelling and field development.
The correctly inferred distribution of a stratigraphic layer's boundaries pre-determines the fluid flow produced by the model to be close to the actual flow. Activities to enhance residual oil recovery are more effective if planned according to the detailed stratification, which means understanding of the geologic aspects of a single area.
The entire knowledge of region's geology and stratigraphy, and any available field data are applied during the correlation and almost all applicable open-hole logging techniques are useful for the purpose of correlation.
The correlation itself is optimised, split into stages and sub-stages to save time and minimise errors.
Spectral Noise Logging Data Processing Technology
Authors: Maslennikova Yu. S. , Bochkarev V. V. , Savinkov A. V. , Davydov D. A. 
Published: October 2012

Abstract
Rational development of oil and gas reservoirs is possible only with efficient monitoring by various well logging techniques. This paper presents algorithms for processing data acquired by spectral noise logging (SNL) in memory mode. The SNL technology is designed to identify flowing reservoir intervals, cross-flows behind casing and tubing and casing leaks by spectral analysis of recorded noise signals.
While moving through a reservoir, fluids and gases create turbulence and rock vibrations that in turn generate noise. This acoustic noise is recorded with a noise logging memory tool consisting of a high-sensitivity piezoelectric hydrophone sensor and an amplifier and data collection module. The tool records acoustic signals in the frequency range of 15 Hz to 60 kHz. The existing SNL technology excludes intense broadband noise created by the movement of the tool in the well.
Useful information is extracted from background noise using a technique based on wavelet thresholding. Spectral noise density in the depth-frequency plane undergoes a wavelet transform. At each measurement depth, several tens of noise signals are recorded to determine mean wavelet coefficients and their typical variance. Then, they are analysed to remove statistically insignificant details from the signal spectrum and to suppress noise components that are present throughout large depth intervals.
The processing of data acquired in tens of wells from various fields has show that the noise features identified by wavelet filtering correlate with open-hole data and are confirmed by conventional well logging techniques.
Supertoxicants: modeling of their formation and distribution caused by the oil spills on the objects of production and transportation of oil
Authors: Khaustov Alexander P. , Redina Margarita M. 
Published: October 2012

Summary
The accidental oil spills are still one of the mostly serious problems in the Russian oil and gas complexes. But until today the approaches to the analyses of the consequences of oil spills can not be recognized as adequate, as well as the approaches to the planning and preparation to the localization and elimination of possible accidents. One of the reasons of this situation is underestimation of danger of the oil components and of the processes of their migration and transformation.
In the process of the geoecological estimation the main attention is mostly paid to the total concentrations of oil products, without considering the processes of the natural fractioning. The consequence of such approach is that the toxic properties of the oil components (incl. polycyclic aromatic hydrocarbons (PAH) and others supertoxicants) are underestimated, the environmental damages are undervaluated, the migration of hydrocarbons in the system "soil – atmosphere – grounds – plants" is inaccurate. The oil transformation products include persistent organic compounds – the individual group of xenobiotics, which main properties are toxicity, perstistence, high migration ability and cumulativeness.
The existing equations of hydrocarbons balance suggest the vertical migration of oil products with the moisture flow in the system "soils – subsoils – capillary zone – zone of saturation". But it doesn't taking into account that the phase transitions of substances are caused by the dominant processes: atmosphere – evaporation and chemical oxidation in soils – biooxidation and biodistruction; in grounds – sorption, diffusion; in capillary zone – formation of entrapped forms of hydrocarbons; in the zone of saturation – spreading of the lens and migration inside as a dissolved form. The age of the oil pollution, the anisotropy of the pollutants movement and their type are very important.
It is necessary to develop the system of the reliable indicators of landscapes' state, taking into account the transformation of oil products and building of the new compounds with the natural substrates, with the estimation of their toxicity and lifetime in the environment.
The multicomponent model of oil products migration with selection of the determined forms of transformation processes is proposed. The 4-zone structure of the upper part of section with oil products' forms and indicators of individual substances as well as natural fractioning processes is modeling. The geochemical markers are proposed – the final products of oxidation and biodestruction, diffusion and sorption of oil components in the environments.
The proposed solutions are necessary to use in the monitoring praxis, as well as for the selection of priority directions of remediation of the damaged landscapes. Considering the necessity of improvement of landscapes remediation efficiency, these studies are very promising.
The Optimal Parameters for Oil Field Development
Authors: Khasanov Mars , Ushmaev Oleg , Nekhaev Sergey , Karamutdinova Dinara 
Published: October 2012

Abstract
This paper describes a new method for selection of well spacing and production rate for an oil field. We express net present value (NPV) as function of well spacing and the production rate. Then we use partial derivatives of this function in order to find the maximum NPV. The equations for partial derivatives are solved numerically. We illustrate an application of our method with examples of Western Siberian oil fields.
Numerical Modelling of Salty Reservoir Waterflooding with Fresh Water
Authors: Bogachev K. Yu. , Milyutin S. V. , Dzuba V. I. 
Published: October 2012

Abstract
In this article, a reservoir waterflood numerical modelling problem is considered for the case when injected water salinity is different from formation water salinity, and taking into account mass transfer due to reservoir salt dilution. Based on a multiphase isothermal black oil model, a new mathematical model is proposed, taking into account the basic physical parameters of the underlying process, such as maximum salt concentration (saturated solution concentration), viscosity and water density dependence on salt concentration, porosity and permeability changes during dilution. It is assumed that dilution speed is proportional to current and saturated solution concentration difference. This model was programmed in a commercial parallel hydrodynamic reservoir simulator [1] and was tested on real field models, showing high numerical effectiveness.
Organizational Capability Development as a Unique Source of Company's Competitive Advantage
Authors: Potapova T. 
Published: October 2012

Abstract
The beginning of the 21st century features the ever increasing globalization, rapid technological and demographical shifts, and numerous mergers and acquisitions. All of the above factors heavily impact organizations forcing them to compete more intensely, to devise new strategies, and introduce new approaches to their operations and customer relations. Globalization offers foreign companies a chance to become local market players and thus pose a serious competitive threat to local operators. Technologies that replace each other at a fast pace make organizations to review their attitude to customers and consumers, and continuously look for new ways to meet their changing demands. Such demographic trends as aging populations and falling birth rates, particularly telling in Russia, are already ringing alarm bells of work force reduction, which triggers tough corporate competition for qualified personnel. All of these phenomena are already visible in Russian and international markets, including the oil industry: nowadays, companies have to fight for best human resources; the time it takes to headhunt world-level technical experts has increased to 12-18 months; and ever more sophisticated methods are used to recruit personnel. In addition, as quality of education offered by Russian petroleum universities deteriorates and the qualifications of their graduates decline, companies have to launch in-house training programs for young specialists.
All of the above factors show that in order to stay afloat and prosper, companies have to revise their attitudes and customs. Traditional approaches to competition are gradually losing their former significance. An organization's success no longer exclusively hinges on its ability to meet the needs of its customers or shareholders, but also on how effectively its processes help it in responding to environmental challenges and changes. Traditional ways of gaining a competitive advantage, such as offering better quality services and products at a lower price, using state-of-the-art technologies, research, etc., must now be complemented with developing an organizational capability or the company's ability to manage its human resources in such a way as to obtain competitive edge. Continuously changing external conditions and the growing significance of uniqueness to company operations have defined this paper's topic. Organizational capability development would enable the company to acquire a source of corporate uniqueness that can hardly be copied or imitated by its competitors.
This article describes a research project carried out within TNK-BP in order to assess the level of its organizational capability and design an organizational capability development program.
Methodology of Fluid Composition Calculation on the Basis of "Black Oil" Simulation
Authors: Devyatov A. , Filippova Y. , Nasibullin A. 
Published: October 2012

Abstract
The paper presents a methodology of hydrocarbon fuid composition calculation on the basis of gas and condensate profiles calculated in a black oil simulator. The methodology is based on the straight dependency of the condensate-gas factor (CGR) and the reservoir pressure (Pres). In order to determine a fluid composition a dependence function between a fraction of a hydrocarbon component and CGR is created using a PVT-simulator. Having a relationship between CGR and a hydrocarbon fraction a fluid composition can be calculated using the average CGR from black oil simulation results. This methodology gives a fraction of every individual component in comparison to composition modelling, where real components should be groupped in pseudocomponents.
Proposed methodology assumes several constraints – the methodology should be applied just for gas condensate reservoirs without oil rims and the reservoir should be developed on depletion. In the work black oil and composition simulation results were compared. The paper can be useful for reservoir engineers working with gas condensates because it allows reducing simulation time without losing information about fluid composition.
Development Options and Justification of Stimulation Techniques for Increased-Viscosity Oil Reservoirs within Messoyakhskoye Project in Difficult Conditions of Yamal-Nenets Autonomous District
Authors: Orlov Alexander , Klimov Mikhail , Samorokov Sergey , Osipenko Alexey , Lyamkina Olga , Bliznyuk Alexander 
Published: October 2012

Abstract
Nowadays Russian oil industry is characterized by oil production deceleration. An ever-growing part of produced fluid is being borrowed by hard to recover reserves, which can be effectively recovered only by means of new highly effective oil recovery increasing technology application. In current situation, the role of the last one has been increasing rapidly due to the fact that oil recovery in Russian oil fields can be increased only by one percent, they are equivalent to several large oilfield discoveries which can provide two or three year oil production in the country. Nowadays the largest Russian oilfields are in declining stage, therefore, the main conditions of oil production stabilization and further Russian oil industry development are implementation of new highly effective technology concepts for oil recovery growth from low permeability reservoirs and hard to recover reserves.
High viscosity oil production is part of hard to recover reserves. However, despite the large high viscosity oil reserves, they are being developed slowly. One of the main problem is the absence of approach to the field development technology selection. Screening of the suitable technology, calculation of technology and economical effectiveness are referred to considerable work efforts which are not feasible at the early stage of the project. This early stage supposes quick determination of several most suitable technologies and evaluation of their effectiveness.