bluuebunny/crossref_metadata_2025_split huggingface dataset:
Oil Spill Response in the Arctic
Authors: Pilipenko Natalja , Lerondeau Benjamin , Vial Eric 
Published: October 2013

Abstract
The context of the Oil Spill Inconvenience of the existing oil spill recovery solutions Problems that we face during the recovery operation 5 important recommendations The Technology The Arctic solution
Despite the significant methods employed, very few- if any- hydrocarbons are recovered at sea. The existing solutions are not capable to recover Oil Spill at difficult weather conditions, rapidly and efficiently, especially in the Arctic. This paper will talk about the patented innovative technology to fight Oil Spill at sea and especially in Artic extreme environments.
First of all we will go through the main disadvantages of the existing solutions to fight oil spill pollution. We will see images and drawings that will explain us the reason of its bad functioning. Then we will put in advance few very important points which must be considered while choosing the solution of oil spill response at sea. And finally we will see in details the technology that permits to recover oil spill at any sea without creating emulsion.
Promising Physical-Chemical IOR Technologies for Arctic Oilfields
Authors: Altunina L.. , Kuvshinov V.. , Kuvshinov I.. 
Published: October 2013

Abstract
The results of laboratory and field tests of physicochemical technologies for enhanced oil recovery are presented for oil fields developed by flooding and thermal-steam stimulation. These technologies can be used in extreme climatic conditions of the Arctic. A promising concept has been developed using reservoir energy or that of the injected heat carrier to generate oil-displacing fluid, gels and sols in situ. Physicochemical bases for EOR have been developed involving chemical intelligent systems: gel-forming and oil-displacing systems based on surfactants self-regulating a complex of properties, optimal for oil displacement, in a reservoir for a long time. Pilot tests of EOR technologies were successfully carried out in oil fields of Russia, China, Vietnam, Oman and Germany using gel-forming systems and surfactant compositions developed at IPC SB RAS. Such systems are commercially produced in Russia and China. The results of pilot tests and commercial application of the technologies for enhanced oil recovery and water shutoff are presented for oil fields with difficult-to-recover reserves including deposits of high-viscosity oils. For effective development of difficult-to-recover oil reserves and further increase in oil production it seems promising large-scale use of advanced complex technologies for enhanced oil recovery combining basic reservoir treatment by water or steam injections with physicochemical methods increasing reservoir sweep and oil-displacement factor at simultaneous intensification of the development. The achieved scientific and technical level of the works enables to create new EOR technologies for hydrocarbon deposits located in the Arctic shelf of Russia, in the Urals and Siberia, as well as reagents adaptable to works in the extreme climatic conditions.
Selection of Subsea Production Systems for the Field Development in the Arctic Environment
Authors: Pribytkov E. A. , Zolotukhin A. B. , Gudmestad O. T. 
Published: October 2013

Abstract
In this paper an analysis of the selection of integrated template structures for the arctic environment is presented. First of all, an analysis of several actual projects has been carried out, where their specifics were thoroughly studied. One of the important parts of the work was devoted to the requirements to integrated template structures conceived in relevant NORSOK, ISO and DNV standards. Arctic metocean conditions that can affect selection, installation and the operational conditions of templates are analyzed. The Main elements of Subsea Production Modules are considered in the work, their specific characteristics and components.
Operations and installation of subsea modules in Barents Sea are considered in the paper. Four scenarios with different numbers of integrated template structures (2, 3, 4 and 6) and different numbers of wellslots in each were analyzed. For each scenario an analysis of related marine operations for the subsea modules installation was carried out. A program for installation cost estimates was built that enabled us to find the optimal scenario for the integrated template structures design. Various parameters affecting the cost of subsea infrastructure were analyzed and studied from different perspectives, e.g. geometrical well pattern system, the distance between drilling centers, drilling and construction costs, etc. Risk analysis regarding the threats and consequences is also performed; risk assessment matrices and mitigation actions are established. As a result, a model for selecting an optimal Integrated Template Structure for the arctic/subarctic regions was built.
Russkoye Heavy Oil Field: Complexity and Exploration Prospects
Authors: Svarovskaya M. G. , Schmidt S. A. , Edelman I. Y. , Zolotukhin A. B. 
Published: October 2013

Abstract
Russkoye field is a unique field containing strategic volumes of hydrocarbon reserves. The pilot projects that lasted more than 20 years show its complexity and ambiguity: high viscosity oil, unconsolidated reservoir, thick gas cap, bottom water, location in the Arctic environment determine the objectives of the seismic, geophysics, development, production and exploitation studies.
This paper announces the key uncertainties that exist in the field and were taken into account to form the current vision of the project solutions for its development: determine principal production profiles, count and mutual location of production and injection wells, consider lateral heterogeneity through an adaptive development system, meeting the critical operating conditions.
Development History Case of a Major Oil-Gas-Condensate Field in a New Province
Authors: Grinchenko V. A. , Anuryev D. A. , Miroshnichenko A. V. , Gordeev Y. I. , Lazeev A. N. 
Published: October 2013

Abstract
The paper describes approaches of the Verkhnechonskoye field development design under uncertainty. Data integration examples for design of the full field development plan are given. Risk management strategy is described. Efficiency analysis of initial reservoir development decisions is made. Approaches to the field development scientific and engineering support are described. Greenfield project typical and unique problems and solutions examples are given (i.e. full field development strategy design, salty sandstone reservoir waterflooding).
The Features of Building the Integrated Model for Development of Two Gas-Condensate Formations of Urengoyskoe Field
Authors: Ignatyev A.. , Bikbulatov S.. , Mukminov I.. , Romashkin S.. , Buchinskiy S.. , Vikulova E.. 
Published: October 2013

Abstract
Most of oil and gas companies are building simulation models for its assets to planning reservoir development. However, even in those cases when the models are reliable and well calibrated to the production history, they do not always reflect the interaction between the different parts of a single system "reservoir-well-gathering system-processing facilities". In other cases when hydrodynamic models are the parts of an integrated model (IM), the models become too complex and require a long time of simulation, what mostly is not very convenient.
This article provides an example of the IM building for the two formations of one of the largest oil-gas-condensate field in the world. Two large gas-condensate reservoirs are in the pilot stage. Full-field development of these reservoirs will increase hydrocarbon production by 5 times (Figure 1). To develop and optimize production plans and the development of the asset, it was decided to use the integrated model. Figure 1Planned production profiles for gas. Formations Ach3–4 and Ach52–3
There were considered different methodologies for constructing the unified model, which combines the reservoir models, models for wells and gathering systems and for processing facilities. Finally the best approach for this project has been selected. The initial compositional hydrodynamic models, which was matched to the production history, have been successfully converted to the Black-Oil models, while giving identical forecasts for gas and condensate and significantly reducing the simulation time. Well models were calibrated to historical data. The formation fluid in the gas gathering network was modelled using a simplified description, while in the models of processing facilities the fluid was modelling with the detailed composition. Despite of the differences in the approaches to the description of PVT properties of gas condensate in different simulators (Eclipse, Gap, Hysys), the developed Integrated Model has demonstrated consistency in the description of fluid PVT-properties. A significant reduction in time of simulation was obtained during the forecast calculations. The results of the Integrated Model were very important for the field development plan optimization, the development of which was previously limited to disparate models of reservoirs and ground infrastructure.
Method of Energetic Interconnected Junction of Large-Scale Inflow to SmartWells Constructed in Elaborated Reservoirs
Authors: Popkov V.I. , Zatsepina S.V. , Khamitov I.G. , Shakshin V.P. 
Published: October 2013

Introduction
There are few people who have doubts concerning the important role of crest faults in migration and formation of oil/gas deposits. The increased fracturing and vags capacity in these zones creates the useful space which under favorable conditions that serves as subsurface storage of hydrocarbons (HC). Complex phase trajectories with the development of fractured reservoirs by numerous wells and rock pressure (stresses) related to them and the seismic emissions of condensed matrix cannot be described by parabolic equations of geological-hydrodynamical simulation. The geophysical and the related hydro-dynamic fields of HC genesis and accumulation, facies and phase borders of porous space in well inflow cases are characterized by the following general abnormal features:
Complicated self-organizing feature of scaled macro-world/micro-world space with no strict structural monitoring; Fluctuations of inflow profiles from zero up to several hundreds of cubic meters per day, that are not coordinated to low porosity and permeability values; Restrictions of deposits by faults, replacements, tidal wave depositions, condensation, and for the wells - by segments with zero inflow from low-permeable, stagnant zones with jammed capillaries and counter-flow impregnation; Tangential pressures, non-equilibrium temperature, viscosity and difficulty (sometimes impossibility), inversion in saturation and pressure, defining the OWC; Convectual/diffusional shear deformations, non-equilibrium lithology, suffusion.
We submit two ways for decisions with multi-scaled regional task: «on a flow basis» from a well towards petro-physics and from lithology of rock space - to a well, by methods of evolutionary transformation of the equations for mass preservation up to energy-steady solutions of Navier-Stoks's equation. We have received analytical and numerically integrated decisions on the interaction of rock pressure (stress) inside the porous space and viscous drain of a well.

Theoretical Substantiation of a Problem
The forecasting of saturation character for sedimentary HC traps is one of most complicated items inn seismic exploration, geo-physics and geological hydro-dynamic modeling of deposits as well as the processes of their development. The problems while simulating these systems is related to the arrangement of various areas inside the formation, which act differently with the actions applied towards them, depending upon the stage of development. With this in mind the model of interaction it substantially different depending upon the type of effect and the distance from the center of this effect. As a result the actual behaviour of the system deviates from model one, giving the solutions that are "asymmetrical?? in specific models.
Problems of Oil and Gas Production in the Verkhnechonskoye Oil and Gas Condensate Field Associated with Halite Depositing
Authors: Chertovskikh E. O. , Lapoukhov A. S. , Kachin V. A. , Karpikov A. V. 
Published: October 2013

Abstract
The paper provides data on chemical composition of formation water and injected water of the Verkhnechonsky Horizon and reviews differences between them. It describes results of in-field observations of inflow of formation and injected waters into producing wells and associated halite depositing during oil and gas production. A summary of causes for halite plugging in the downhole equipment is provided. Estimation of skin factors and productivity ratios are done for cases of halite redeposition in bottomhole zones of the formation. Technological solutions for assurance of halite deposition control during oil and gas production in the Verkhnechonskoye Oil and Gas Condensate Field are described. The actual data are compared to data available from publications on the problem of halite/chloride depositing during oil production. A theoretical basis is proposed for understanding of geochemical processes of halite depositing in the bottomhole zones in the Verkhnechonskoye Field.
The Verkhnechonskoye Oil and Gas Condensate Field (hereafter the VC Filed) is located in Katanga District of the Irkutsk Region in East Siberia (Extreme North Area). The main oil and gas reservoirs are placed in the Verkhnechonsky Horizon (83% of recoverable reserves). (Figure 1). Figure 1Scheme of faults and formation borders in the Verkhnechonskoye Field
Features of Studing Oil and Gas Fields to the Full-Scale Development in Comlete Autonomy by Analogy Tagulskoe Fields
Authors: Lachugin D.. , Rusanov A.. , Gabisiani G.. , Maltsev A.. 
Published: October 2013

Abstract
CJSC "ROSPAN INTERNATIONAL", a subsidiary of OAO "NK" Rosneft ", is currently engaged in the preparation for full-scale development of oil fields in Yamal and the north of the Krasnoyarsk Territory.
One of these fields – Tagulskoye, located in the north of the Krasnoyarsk Territory. Infrastructure and road network in the area of the field is absent. Transportation of goods is carried out on the winter road in the summer – water and helicopter transport. Developed by the near field – Vankorskoye, located 45 km to the north.
Active research field began in 2009 with the implementation of the pilot area number 1 (section pilot development). In 2009–2010, drilled five wells, including four with horizontal shaft. Conducted in 2010–2013 set of studies aimed at reducing the geological, technological risks, optimize system design to improve the reliability of the forecast of technical and economic indicators.
The article summarizes the main results of pilot projects, analyze their performance. A comparison of predicted and actual characteristics of reservoirs, mining potential wells. The approach to preparing the fields to infrastructure constraints.
A Method to Determine Optimum Well Spacing for Oil Rims Gas-Oil Zones
Authors: Khasanov M. M. , Ushmaev O. S. , Samolovov D. A. , Ovcharov V. V. , Dmitruk D. N. , Timofeeva T. N. , Andjukaev C. V. 
Published: October 2013

Abstract
The estimate of the rentable reserves and number of wells required to exploit a reservoir are among the most important variables required to decide on an oil field development.The present paper describes a method to determine both rentable oil thickness and optimum horizontal well spacing in gas oil zones of oil rims with massive gas cap. We propose a techno-economic model of oil rim development that allows expressing Net Present Value as a function of well spacing, filtration and volumetric characteristics of a reservoir, well, infractructure and lifting costs and oil price at wellhead. Basing on the proposed model, we derive dimensionless criteria to determine profitability and optimal horizontal well spacting for oil rims gas-oil zones.
The Potential to Increase Heavy Oil Production from Complicated Carbonates Applying the Intelligent Well Technology
Authors: Pchela Konstantin , Ursegov Stanislav , Mulyak Vladimir , Chertenkov Mikhail 
Published: October 2013

Abstract
This article is dedicated to generalize the actual data obtained during the start up of production and testing processes conducted in the horizontal wells with the intelligent completion in the Permian-carboniferous heavy oil reservoir of the Usinsk field, located in the extreme north-east of European Russia. The applying intelligent equipment meets the aspirations to maximize the effectiveness of horizontal production wells during steam flooding.
Energy-Efficient Oil and Gas Fields Operation on The Basis of "Smart" Wells Equipped with Multiphase Flow Meters
Authors: Shumilin Vladimir , Shumilin Sergey 
Published: October 2013

Summary
The lack of information about the production rate of each well in the real-time makes it difficult to choose the correct working time of borehole pumps and leads to not optimal operation of the field. Under these conditions, the most important item is development of energy-efficient technologies for oil production by electrical pumps, where periodic pump operation is caused by the minimization of the edge water volume, lifted along with the oil.
This paper describes a method of well and field operation where the volume of crude oil and edge water is determined in real time by a multiphase flowmeter installed on a well, and the pump is switched on/off automatically after the analysis of volume/ percentage of the produced edge water.
Wavelet-Based Transform Analysis for Non-Darcy Gas Flow Noisy Data Interpretation
Authors: Ivaschenko D.. , Davletbaev A.. , Baikov V.. , Bulatov I.. , Seidl G.. , Simon E.. 
Published: October 2013

AbstractGas well testing (GWT) is one of the principal methods for estimating its flow potential and to determine reservoir properties and bottom-hole area conditions. Further, it allows to make use of non-linear filtration influence. Reliability of GWT results is important for the choice of field development strategy and production stimulation.The paper focuses on non-linear filtration research, but unlike to well-known purely theoretical results, we developed a set of guidelines designed to conveniently process and interpret field data. We state that modern mathematical methods such as wavelet analysis and accurate planning of field experiments are key in order to acquire more reliable information about reservoir and well properties. This approach can further be applied to lay out the Arctic shelf gas reservoir engineering and planning the well intervention techniques.
Method for C5+ Content Estimation in Produced Gas Condensate
Authors: Rudenko D.. , Rymarenko K.. 
Published: October 2013

Abstract
Gas condensate field development requires tight control of the amount of the condensate content (C5+ components fraction) in produced gas condensate. Monitoring of C5+ content and optimization of the amount of condensate produced is required for the maximization of the condensate production and as response on the limitations posed by surface equipment and transportation system.
Contemporary multiphase flow metering (MPFM) technologies although capable to monitor amount of condensate produced are strongly dependent on quality of the models used to estimate fluid phase properties. It is specifically important for gas condensate fields where no single fluid model is applicable for the full range of production history. Therefore development of the reservoir simulation model capable to reproduce dynamics of the condensate production during the MPFM job is necessary to validate quality of the measurements. Nevertheless condensate content in produced fluid depends not only on current production parameters but is also sensitive to the production history and problem of the optimal production strategy selection by the means of traditional reservoir simulations requires significant amount of simulator runs and is computationally expensive.
Possibility to simulate processes in the reservoir with accuracy sufficient to simulate dynamics of gas condensate recovery and would allow simulation of the MPFM process for the gas condensate wells was demonstrated for the dual energy gamma Venturi meters (Vx flow meters). Derived from the analysis of the dynamics of the condensate production obtained using developed reservoir simulator model "Proxi" model for fast C5+Tot estimation was proposed. Capability of the "Proxi" model to get fast estimation C5+ content for given gas production rate and cumulative gas production were demonstrated and possible solution for condensate production optimization for the group of the wells based on the proposed "Proxi" model was suggested.
The Role of RADARSAT-2 to Support Arctic Shipping
Authors: Staples Gordon 
Published: October 2013

Abstract
Since the launch of RADARSAT-1 in 1995 and RADARSAT-2 2007, these SAR sensors have played a pivotal role as a key source of information for the production of ice charts and the provision of near-real time data to support shipping. The RADARSAT-2, wide-swath ScanSAR modes coupled with dual polarized imaging capability are ideally suited for ice mapping applications. The space segment is augmented with a ground segment that has been designed to meet the needs of rapid data processing and delivery of ice information. The wide swath-width combined with high-latitude areas-of-interest provides multiple imaging opportunities per day. Ice-type discrimination, for example first-year versus multi-year ice, can be achieved by using HH polarized data, and HV polarized data can be effectively used for ice-water discrimination. To meet the needs of end-users who require ice products in near-real time, MDA has developed automated ice-water discrimination algorithms and techniques to estimate ice pressure. RADARSAT-2 data are routinely used to support ice-breaking operations, commercial shipping, seismic exploration, and offshore oil drilling. A key requirement to support these activities is to provide the data in an interpretable and interoperable format that best suits end-user needs.