bluuebunny/crossref_metadata_2025_split huggingface dataset:
Applicability Appraisal of the Multiphase Transport Technologies of Associated Petroleum Gas in the Arctic Shelves of the Russia
Authors: Levin I. V. , Glazkov O. V. , Malyshev S. A. 
Published: October 2012

Summary
In this paper is given an estimate to the resource potential of the Artic shelf of the Russia and prospects of its development. The comparative analysis of multiphase technologies of wellstream gathering, applicable for conditions of Arctic shelf on an example of fields of the Barents and Kara Seas, is carried out. Various aspects of the joint transport system application of gas hydrates and oil on one pipeline for solving the problems of associated petroleum gas utilization on an example of the Artic shelf fields are considered.
Well Test for In-Situ Determination of Oil and Water Relative Permeabilities
Authors: Zakirov S. N. , Indrupskiy I. M. , Zakirov E. S. , Anikeev D. P. , Vasiliev I. V. , Severinov E. V. , Gaidukov L. A. , Rodionov A. E. , Lachugin D. S. , Tsagan-Mandjiev T. N. 
Published: October 2012

Abstract
Relative permeability data are very important for reservoir engineering, because these parameters highly influence waterflooding efficiency, oil/liquid production forecast and therefore economics of an asset.
Core experiments for determination of relative permeability curves are point-wise and do not completely reconstruct formation conditions. Application of core relative permeabilities on field scale may lead to inadequate modeling of real flow conditions and result in actual production not complying with forecast during commercial exploitation.
Current structure of Russian Federation oil resources is such that most of the promising oil and gas regions are at full autonomy conditions, with lack of year-round road connection and infrastructure for production transfer. Thus, new techniques are required for acquisition of parameters important for reservoir engineering (including in-situ relative permeabilities), which are well-suited to production limits during pilot field study program.
A promising approach to in-situ determination of flow parameters is well testing. A well test technique for determining oil and water relative permeabilities developed at OGRI RAS is based on generation of multidirectional two-phase flows and provides data for determination of an extended set of formation characteristics. Interpretation includes special algorithms and software with application of numerical methods for direct problem solution and optimal control methods for inverse problem solution.
Well test for determination of in-situ relative permeabilities described in the paper has been performed at an oilfield in Western Siberia at conditions of arctic climate and full autonomy.
Results of the well test led to: ♦correction of relative permeability data earlier obtained from core analysis,♦establishing higher water mobility in full range of water saturations and probably no increased threshold of water mobility (critical saturation);♦adjustment of oil and liquid production plan for full field development project, which resulted in more reasonable estimation of asset investment attractiveness and optimal decision on recovery strategy.
Selection of the Optimal Type of Fractured Well Completion Based on Simulation of Highly Heterogeneous Reservoir
Authors: Gataullin T. I. , Eliseev P. I. , Zavalin F. S. , Lutfullin A. A. 
Published: October 2012

Abstract
The basic method for oil-saturated, low permeability, anisotropic reservoir is hydraulic fracturing. Currently, the technology of a multi-stage fracturing in horizontal wells (hereinafter - the Multifractured HW) is rapidly developing, allowing the creation of several fracs in several areas of the horizontal well within the one workover.
In this paper the sequence of actions designed to calculate the targets of development with the Multifractured HW and for comparison with grids of vertical fractured wells. The main problem of calculating the field development plan with the system of the Multifractured HW on full field simulation model is the lack of reference to both the input flow rates of wells, and the dynamics of decline. To set up a simplified representation of such wells in the full simulation model the detailed sector model was created for different types of completions: Multifractured HWFractured vertical well
The sector simulation was run for different reservoir properties, and the dependence of the flow rates ratio in the pseudo-steady state flow was calculated.
The paper presents the results of Multifractured HW drilling, comparison of design and actual performance, the lessons learned.
Computation of Reservoir Properties Based on 3D-Structure of Porous Media
Authors: Korost D. V. , Gerke K. M. 
Published: October 2012

Abstract
Pore structure is one of the main factors defining reservoir properties of rocks. Conventional estimations of such properties using only limited 2D data from thin sections using different approximations are usually inaccurate.
In recent decades different numerical methods were developed to quantify flow and other physical properties on micro-scale. Each method has its own advantages and drawbacks, so utilization of more than one of approaches is reasonable, depending on the study case.
Recent progress in X-ray micro-tomography and some other techniques allow precise determination of three-dimensional structure of rocks, however, a trade-off between resolution and sample size is usually unavoidable. Some amount of porosity (we call it "under-resolution") is usually not visible on X-ray scans or thin-section low resolution images. Unlike permeability, it may play an important role in resistivity, capillary curve shape and other properties.
The main aim of this contribution is to verify petrophysical modeling approach on a collection of sandstone samples with wide range of pore space configurations. At first, our 3D structure obtaining method using X-ray microtomography is justified via detailed laboratory vs. tomography porosity measurements comparison. Next, permeability is determined for all samples using network-model extracted from 3D structure scans. Calculated formation factors and capillary curves in many cases deviated from experimental values, especially for samples with high under-resolution porosity. The influence of invisible porosity is also supported by coordination number correlations with other physical properties for sample within the same group (same reservoir type). To account for under-resolution pores invisible on X-ray scans different approaches can be utilized based on artificial addition of under-resolution porosity into numerical sample: NMR measurements, mercury porosimetry, or stochastic reconstructions from high resolution 2D cuts.
Effective Management of Pilot Projects
Authors: Alekseeva V. A. , Karfunkle J. 
Published: October 2012

Abstract
Each year, the market offers new technologies and approaches, which, provided they are properly introduced, can make a positive contribution to business development of oil companies in depleting brownfields and greenfields with complicated conditions. Production increments supported with conventional technologies have been on decline from year to year.
This work offers approaches to managing the process of searching, introducing, and monitoring optimum technologies providing for economically feasible access to reserves, oil recovery enhancement, and cost reduction, which can be used by oil and gas companies to improve their performance.
In view of current and future field problems, the following technological priorities have been defined: oil recovery enhancement techniques, effective drilling, seismic surveys, water flooding, etc.
Key instruments of technology strategy implementation include methodology, process regulations, and information systems for assessing efficiency of decisions taken.
In order to develop the innovational culture, it would be desirable to hold regularly regional and corporate Technology Forums, develop knowledge bases that would ensure exchange of experience and development of personnel competencies.
To evaluate pilot project results, information systems should be introduced, which would provide for monthly monitoring of pilot project performance evaluation criteria.
If a technology is successfully tested in the course of the pilot project, broad-scale scaling-up of this technology is started. It implies updating the technology scaling-up potential, general forecast of economic results, and scaling-up program monitoring during the year.
Risk mitigation and success of the new technologies program depend on managing the initiation, monitoring, and personnel motivation process.
Introduction of proposed methodologies, processes, criteria, and information systems for prompt evaluation of pilot project results during wellwork operations helps take timely and high-quality management decisions in the course of implementing the new technologies program, which is important for companies holding a balanced portfolio of oil brownfields and greenfields, gas fields, and fields with unconventional hydrocarbon reserves.
Geosteering: Experience in Practical Use at the Ust-Tegusskoye Field, Analysis of Efficiency
Authors: Ustinova Larisa , Makarova Ekaterina , Sokolov Artem , Osepyan Suren 
Published: October 2012

Abstract
The paper reviews practical applications of geosteering to horizontal well drilling and evaluates its efficiency for horizontal drilling. On Ust-Tegusskoye filed more then 30 horizontal wells were steered using 3D geological model.
One of key problems in geosteering process is limited ability to understand the location of the wellbore relative to the target object (productive layer, sand interval). The traditional set of data – structural maps build from seismic and pilot wells does not allow building fine structural capable to ensure successful drilling. But building the modeling workflow allows to simulate many possible locations of horizontal wellbore between top and bottom of reservoir, find the most probable location and minimize risk of unsuccessful drilling. Local update of the geomodels in the relatively small regions containing newly drilled wells helps getting production forecasts from flow simulator in reasonable time.
Recently large attention is paid to developing innovative approaches to the steering of horizontal wells.
The key requirement to the geosteering process today is landing well trajectory not only into pay part of productive layer, but into most efficient part of reservoir with minimal penetration of dense sub layers. For that the whole set of technological solutions exists ranging from optimization of pilot wellbore locations and finding best possible well profiles on geological and flow simulation models to the real time geosteering.
On Ust-Tegusskoye field the number of drilled horizontal wells grows every year: in 2009 there were 3 wells, in 2010 - 5 and in 2011 - 15. At the first half of 2012 9 horizontal wells were drilled (Figure 1). Minimal thickness of target layer for horizontal wells is 2.5 m. Maximum length of horizontal part is 832 m.
In spite of continuous improvements in drilling technology the problem of finding borehole position within top and bottom of target layer is still actual. Standard set of G&G information – seismic based structural surfaces and pilot wells does not allow building geomodel with reliability required for successful steering of horizontal well. Wrong positioning of well trajectory make cause it to deviate from target layer – so effective length of the well will be significantly reduced.
Electromagnetic sounding in deviated and horizontal wells: mathematical modeling and real data interpretation
Authors: Epov Michael I. , Suhorukova Carina V. , Nikitenko Marina N. , Gorbatenko Aleksey A. , Arzhantsev Vitali S. 
Published: October 2012

Abstract
The features of numerical VEMKZ data interpretation in deviated and horizontal wells entering oil-saturated and water-saturated formations are observed. On the basis of mathematical modeling of VEMKZ signals for typical hole path of horizontal wells the effects caused by crossing bed boundaries and thin layers with high resistivity are shown. The influence of electrical anisotropy on signals has been investigated. The influence of borehole rugosities and tool eccentricity was studied. The programs of numerical modeling have been developed at Institute of Petroleum Geology and Geophysics (IPGG) Siberian Branch of Russian Academy of Sciences.
Algorithms and methodological procedures are used for numerical interpretation of VEMKZ data (including SKL set data) in case of thin reservoir, electrically contrasting shoulder beds and thin interlayers. The eccentricity, borehole rugosity, sine-shaped and spiral well bore influence on signals was investigated in case of typical hole and tool diameters, the programs of numerical correction have been developed. The fact that influence of electrical anisotropy in deviated well causes apparent resistivity increase is demonstrated. Numerical inversion VEMKZ data obtained in well entering terrigenous reservoir under-lied by thin layer with high resistivity have been processed. Starting model for inversion is generated by taking direct current data into account. Examples of real VEMKZ data interpretation are demonstrated.
For investigations in deviated and horizontal wells the approach for finding true formation resistivity in thin reservoir using high-frequency induction measurements was proposed. This approach based on numerical signal modeling for deviated tool in horizontally-stratified earth. Algorithms for electrical anisotropy evaluating and thin-layer parameters estimating are observed.
Geological Modeling of Fractured Carbonate Reservoir of Paleozoic Basement in Western Siberia with Application of 3D Seismic Data
Authors: Pylnik S. V. , Shaporenko S. N. , Babov V. N. , Shtokolova M. N. 
Published: October 2012

Abstract
The methodology of geological modeling of fractured carbonate reservoir of Paleozoic basement in Western Siberia with application of 3D seismic data is described. The construction algorithm of three-dimensional seismic trends and the using methods of these trends for modeling are presented. The facies model of the reservoir and the structural-tectonic analysis methodology are described. History matching results which are presented at the end of the paper show the correctness of the used technique.
Uncertainty analysis as decision making tool for green fields of Yamal region
Authors: Biryukov S. D. , Zakirov I. S. , Severinov E. V. , Gaidukov L. A. , Miroshnichenko A. V. , Kudlaeva N. V. , Endalova Y. V. , Chameev I. L. 
Published: October 2012

Abstract
The new green fields of Yamal region and Eastern Siberia today is one of the important areas for oil production during next 10 years. One of the key problems of field development in these regions is poor infrastructure and lack of input data of geology, target formations and fluids properties. For decision making during field development preparation stage its necessary to carry out estimation of possible scenarios.
Analysis of uncertainty will provide a range of changes in reserves and oil production profiles which can help to estimate economical part of field development project. Also these results can be used for design pipe lines and surface facilities.
Authors of paper suggested the approach how to estimate uncertainties in cases of lack input data of formation based on data of Russkoye oil field.
Accounting VTI Anisotropy in the Performance of Pre-Stack Depth Migration On West Siberian Data
Authors: Khromova I. Y. , Grechishnikova T. A. , Nadezhkina D. Y. 
Published: October 2012

Abstract
These days "simple" oil fields and reservoirs are well researched and oil companies face a complex task of improving the accuracy of the study of small capacity collectors, or fractured reservoirs. These new challenges require new methods for processing and interpretation of seismic data.
Significant velocity anomalies are usually observed in areas with complex geological structure, e.g. in the presence of faults, salt-dome tectonics, or steep dips of the reflecting horizons. Time migration in such environments can not get a reliable image of the complex geological structures. Its resultis distorted due to underestimated lateral velocity changes. Successful method of restoring the correct structure of the environment in complex geological conditions is a pre-stack depth migration. During depth migration seismic data are transformed to depth image of the geological structure, with correctly positioned reflecting boundaries and correct dips due to rightful consideration of seismic-wave refraction/. Comparison of the results of time and depth prestack migration is presented in Figures 1 and 2.
These days, we are using a large number of algorithms to perform pre-stack depth migration, whether based on ray tracing methods or the wavefield restoration: classical Kirchhoff migration, migration of full-wave solutions on the basis of the wave field (WEM), reverse time migration (RTM), different variations of Gaussian Beam, etc. Which algorithm is used usually depends on the geological structure of the area and processing goals. One of the determinants for pre-stack depth migration performance for each algorithm is the quality of deep-velocity model.
Salym Petroleum Development: Experience and Lessons in WRM on Salym Group of Fields
Authors: Alexeyev A. , Volokitin Ya. , Karnaukh D. , Domnin E. , Bydzan A. , Pickles M. 
Published: October 2012

Summary
Reservoir monitoring in the course of current field development is the key factor for continuous short-term production optimization and achievement of best economics throughout the lifecycle of the field. Therefore, Salym Petroleum Development (SPD) carries out a set of actions focused on controlling current development parameters.
The report describes the processes of planning, geological and downhole logging data acquisition and methods of interpretation thereof during the active development phase of the Salym group of fields. Key emphasis is assigned to analysing the efficiency of different methods for solving the key tasks of development control.
A Robust Method to Quantify Reservoir Connectivity Using Field Performance Data
Authors: Krasnov V. , Ivanov V. , Khasanov M. 
Published: October 2012

Abstract
An improved method of well-to-well connectivity evaluation is proposed. The method is based on combination of two approaches developed by now - capacitance model (CM) and Multiwell Productivity Index (MPI). Multiwell productivity index is evaluated independently of production data basing on well location geometry and average reservoir properties. Connectivity coefficients, derived from MPI are used as constrains when searching for CM solution. Following the physical meaning of the problem the capacitance model is improved by adding a constraint which was possibly overlooked by previous researches. These improves convergence of optimization problem which is inherent part of CM algorithm and enables to apply it to evaluate waterflood for real reservoir with more than 60 wells.
An injection and production rates as well as bottom-hole pressure data can yield a lot of valuable information about well interaction and therefore, reservoir characteristics, if they are analyzed properly. For example, such analysis can reveal a preferential flow direction throughout the field or quantify interaction of injector to surrounding producers that enables to reduce ineffective water circulation. Proposed method combines CM and MPI approaches which both got their own advantages and drawbacks. Capacitance Model provides quite detailed analysis and quantifies the well interaction. Thus, it allows us to learn more about the reservoir structure as well as to optimize the waterflood, but it turns out to be unstable when applied to real data. Also it misses an important constraint connected with a physical meaning of CM parameters. The stability of CM can be increased by using an MPI approach. To this effect, we use analytical MPI values in construction of a regularizing functional within the CM's algorithm.
The method was applied to one of Rosneft fields to establish well interaction pattern. Recommendations were given to improve waterflood efficiency.
Memory Magnetic Imaging Defectoscopy
Authors: Arbuzov A. A. , Bochkarev V. V. , Bragin A. M. , Maslennikova Y. S. , Zagidullin B. A. , Achkeev A. A. , Kirillov R. S. 
Published: October 2012

Abstract
This paper presents downhole magnetic imaging defectoscopy (MID) in memory mode, its key principles, differences from other corrosion logging technologies, and some results of its application in oil wells.
The MID technology is designed to check the integrity of magnetic and non-magnetic tubing and casing strings in oil and gas wells. It can be used to detect various defects, corrosion and mechanical wear, and to assess the quality of perforations.
The MID tool contains two high-sensitivity sensors: a short generator/receiver coil and a long one with short relaxation times to analyse responses even at early times of 0.1 ms. The short coil generates a short, low-amplitude electromagnetic pulse and records a response from the first metal barrier, normally tubing, where as the long coil generates a long, high-amplitude electromagnetic pulse and records a signal travelling a much longer distance of up to 13 inches to record the total response from tubing and casing. Mathematical processing of these responses can determine the thicknesses of the first and second metal barriers.
An independent power supply allows logging to be performed on slickline, which substantially reduces operating costs and enables the use of magnetic imaging defectoscopy for well monitoring to prevent leak and corrosion related incidents and thus increase environmental safety in the field. The wide use of memory magnetic imaging defectoscopy will substantially reduce the number of well incidents and expenses for remedial jobs.
Improving the efficiency of oil and gas field development by optimizing the operation of injection wells
Authors: Ridel A. A. , Margarit A. S. , Garifoullina R. A , Mazhar V. A , Almukhametov M. A. , Petrov I. A. 
Published: October 2012

Synopsis
Optimization of flooding - is a package of technological solutions, which includes analysis of operation of injection and production wells,."performance" of the flood front in combination with the analysis of geological view of fromation and remaining recoverable reserves.
Accurate choice and optimization of technologies of flooding defines the success of the effective development of fields.
In spite of to the state of knowledge of this process, its importance in oil extractio, makes its developers to pay more efforts for better understanding of pecularities of the flooding and improvement of the efficiency of the process. One of the issues, which require more detailed study, is forming of man-induced unsteady fracttures (auto-fracturing) during injection wells operation and their influence on the efficiency of the displacement processes.