bluuebunny/crossref_metadata_2025_split huggingface dataset:
Creating of Multivariant Geological and Statistical Model as a Solution for Assessing the Quality of Reserves
Authors: Sitnikov A. N. , Belozerov B. V. , Glozhik R. Yu. , Muzychenko A. A. , Vasilyev M. O. 
Published: October 2015

Abstract
The paper suggests an algorithm for the building of multivariant Geological and Statistical Model (GSM) based on the analysis and comprehensive assessment of multidimensional dependencies among geologic, technological and economic parameters for the qualitative ranking of target reserves by the degree of quality, which is determined by the feasibility of their extraction. The key methods that were used to study the impact produced by the geological, technological and economic parameters were the methods of assessing the investment potential profitability and development history analysis, multidimensional statistical analysis and simulation etc. The existing UN Framework Classification experience was used. The term "reserves quality" means the economic feasibility of recovery under specified geological characteristics and using available technologies, and under current economic conditions and existing tax rate, was introduced by the authors.
Concept Baseline for the Development of a Major Complex Field in Eastern Siberia using Flow Simulation
Authors: Levanov A. N. , Belyansky V. Y. , Volkov I. A. , Anuriev D. A. , Grinchenko V. A. , Neftegazodobycha Taas-Yuryakh , Musabirov T. R. 
Published: October 2015

Abstract
A case study of Srednebotuobinskoye Field, the oil deposits of which are confined to gas-oil-water and oil-water zones, describes the evolution of design decisions for development after the first year of asset operation. The first production data showed the need for separate solutions for under-gas-cap and water-oil zones, and the formation of a new field development concept, and their justification was the purpose of the work the results of which are shown in this paper.
The difference with the previously performed work lies in the fact that development decisions were made based on the results of multiple runs on a variety of complex flow simulation models - fine-cellular and full-scale.
The outcome of the study was the creation of a new development concept which provides different design solutions for under-gas-cap and water-oil zones.
The value of the work lies in the fact that the decisions involve different oil displacement processes in different parts of deposits, which affects the oil recovery rate and as a consequence the whole field development and infrastructure complex.
The Main Tendencies of Water-Induced Hydraulic Fracture Propagation
Authors: Trimonova M. , Dubinya N. 
Published: October 2015

Abstract
A mathematical model of water-induced hydraulic fracture propagation is introduced in the paper. The main point of the proposed model being compared to the existing ones is the correct asymptotic behavior: the classical models of hydraulic fracture propagation being implemented for solving the problem of water-induced hydraulic fracture lead to infinite fracture growth. We use a special method of taking the leak off into account to get around this issue. It includes the analysis of poroelastic effects in the vicinity of the fracture. Applying this method to solve the problem of water-induced hydraulic fracture propagation a following result can be obtained: the fracture continues to grow as long as the leaks are less than the amount of fluid injected. Nevertheless, there is a moment when the leaks become equal to injection and thus the fracture growth stops. So the fracture length becomes a bounded function of time and the upper limit of it may be calculated and used in reservoir development as a final length of water-induced hydraulic fracture.
Development of Algorithms to Control the RPM System under Full Implementation of the Swag Injection Technology at Roman Trebs' Oilfield
Authors: Nadezhdin O. V. , Lutfurakhmanov A. G. , Vinogradov P. V. , Efimov D. V. , Sergeev E. I. 
Published: October 2015

Abstract
To maintain reservoir pressure and to increase efficiency of oil production at Roman Trebs' oilfield it is planned an injection of water-gas mixture into reservoir. Reservoir pressure maintenance (RPM) system is a branched double-tube network – gas and water pipelines are laid in parallel in all sections. Water pipeline provides water delivery from pad pumping station (PPS), and gas pipeline delivers gas from compressor station (CS) to multywell pads of injection wells. Further water and gas are mixed on well pads in individual mixing devices, and water-gas mixture is pumped into injection wells. Control of water and gas volumes injected in each well is achieved by means of control valves mounted on gas and water supply lines of each mixer.
Pipeline of RPM system with injectors represents a complex dynamic facility and managing such complex dynamic object is a problem with a nontrivial solution. This problem is complicated by the fact that it is planned injection not of a single-phase liquid but two-phase water-gas mixture. Moreover, problem of controlling injection of water-gas mixture includes maintaining a certain ratio of water and gas in each well. This article shows problems of complex object management (multidimensionality, multistability, influence of injected agent's properties) and ways of solving these problems.
While developing control algorithms, RPM system was studied as a nonlinear non-steady multidimensional control object with vector input and output. Characteristics of transient modes were defined. There were studied the algorithms of structural-parametric identification of dynamics of multidimensional control object. Various options of regulator structure were investigated: PID-control, modal PID controllers, controllers with a higher degree of astatism, controllers with identifiers.
Based on analysis of simulation results there were found the recommended paths of well starting and decommissioning. Similarly, recommendations were made on settings changes. In addition to lower level of water and gas control it was proposed to apply an additional upper level control of wellhead pressure, which allows operation of well, even when settings are taken not from work area.
As a result, it was shown how developed control model allows continuous operation of entire RPM system with a desired injection level.
Solid Expandable Tubular Systems: Advantages and Prospects of Application in Russia
Authors: Glebov S. , Kulikov S. , Sidorenko K. 
Published: October 2015

Abstract
Over a number of years production casing leaks have been one of the major issues of oil well operation in Russia. Experts believe that this issue is one of the main reasons of oil well shifting from the active well stock into temporarily shut-in wells.
The share of shut-in wells in Russia has reached 15% of the total oil well stock without any significant changes in recent years.
It is evident that conventional solutions providing for smaller size production casing running and cementing to surface are not cost efficient.
Operators are surely interested in alternative solutions being less material, tool and time consuming.
In this context, solid expandable systems deserve close attention as their application will enable to reduce both work costs and nonproductive time.
Operator's benefits from using solid expandable systems for production casing leak repairs include:
Reduction of production decline rates at brown fields; Extension of field producing life; Reduction of shut-in well servicing costs.
Solid expandable tubular systems significantly differ from each other in the design of expandable tubing (patches), the expansion method, and, correspondingly, the complex of equipment applied.
This article describes one of the most common solid expandable tubular systems, presents an analysis of its application geography, and provides a case study of this system application in Russia.
New Approach for Gas Lift Optimization Calculations
Authors: Khabibullin R. , Burtzev Ya. 
Published: October 2015

Abstract
This work is devoted to development of gas lift optimization calculus methods applicable under high uncertainties with initial data. The initial data that can be missed or have high degree of uncertainty is the gas injection rates, gas oil ratio, bottom-hole flowing pressure, and productivity index. Optimization refers to the assessment of the well's current operation mode from the point of view of gas lift efficiency enhancement, the possibility of gas injection reduce or oil production increase. An approach - the construction of a mathematical model of gas lift wells based on the multiphase flow correlations and gas lift equipment modeling. The proposed model allows to analyze well behavior, identify the correct solution from several possible describing the observable parameters. It allows evaluating wells optimization potential using current gas lift installation and can be used to design new one.
Flow assurance in gas-gathering networks of two gas-condensate formations of Urengoyskoe Gas-Condensate Field
Authors: Bikbulatov S. M. , Buleiko V. V. , Mukminov I. R. , Bikbulatov R. V. , Vinokurov V. N. 
Published: October 2015

Abstract
The last 18 years CJSC "Rospan International" is producing gas and condensate from the two formations of The Urengoyskoye Gas-Condensate Field located in the Yamalo-Nenets Autonomous District. By 2016, the company expects a significant increase in production capacity, with an annual production of hydrocarbons more than 18 billions of cubic meters. About 250 wells are planned to drill at both formations. Gas transport is carried out based on the collector-beam pattern onto the GTU (gas treatment unit), which at this stage operates on the subcooling separation scheme. In the long term it is expected to complete modernization of the GTU.
Multiphase flow transported through collectors is seen as a dynamic phenomenon and is subject for dynamic modeling. Non-stationary processes can often be observed in the gas-gathering networks. Moreover, a stable (close to steady state) stage often is not achieved, and thus the use of stationary calculation methods may not correctly model the real situation.
In order to provide current and future control of production processes that occur during the operation of gas-gathering networks, and to provide the necessary engineering support, models of gas-gathering networks in the OLGA software have established.
In this article authors present an analysis of calculations and offer recommendations based on results of dynamic modeling of transport processes in the production system using OLGA software. Analysis of stability of flow in gas-gathering system has been performed for an abnormality in the piping due to the formation of hydraulic slugs. Problem areas were examined, and recommendations for elimination of the negative phenomena thus regimes of transport products have been excluded in which the violation of a stable flow regime in the pipeline will be observed. The reasons of wells self-killing were investigated.
Environmental Monitoring of Arctic Waters with Unmanned Bivalve Biosensor Technology: One Year of Background Data Acquisition in the Barents Sea
Authors: Massabuau Jean-Charles , Gudimov Alexander , Blanc Philippe 
Published: October 2015

Abstract
Adequate and efficient environmental monitoring is a key element of the environmental risk reduction process in the Oil & Gas industry, all the more where sensitive areas in harsh environmental conditions are at stake. This is the case in remote and extreme cold places such as the Arctic, where robust systems are required to withstand adverse climatic conditions and minimize intervention of man. Sharing clear and easily understandable information (as biological indicators) in total transparency with stakeholders, including local population, is an essential issue for both environmental and societal purposes. Working with public research organizations under the responsibility of governments is another key issue.
Within this scope, an innovative online biomonitoring technology, High Frequency Non Invasive Valvometry, based on the use of bivalves equipped with light electrodes has been successfully tested during one year in a bay located in the North-East of Murmansk (Barents Sea). This has been done through a joined project between CNRS, the French National Center for Scientific Research, MMBI, the Murmansk Marine Biological Institute in Russia, and TOTAL Exploration & Production. Groups of bivalves (Icelandic scallops and Blue mussels) were placed at 15-18m under sea level, with minute electromagnets glued to each of their valves to record opening and closing activity. A remote intelligent device composed of a waterproof case next to the animals and a card out of water (the whole thing is a low power, 1W, fully-rugged Linux-running microcomputer) was installed. The master unit where data are automatically handled is in Arcachon, France. The connection uses GPRS & internet. The data are publically monitored on MolluSCAN Eye website (google molluscan eye).
Daily acquisition of data during one year has demonstrated the ability of the technology to automatically rebuild easily understandable biological rhythms, growth rates and spawning activities of the bivalves. This includes activity during the harsh Arctic winter period. This technology opens the gate to "intelligent" monitoring of aquatic environments enabling sensitive and continuous assessment of harmfulness of industrial impacts, in particular for the Oil & Gas industry.
System Approach to Planning the Development of Multilayer Offshore Fields
Authors: Lubnin A. A. , Afanasiev I. S. , Yudin E. V. , Fedorchenko G. D. , Sansiev G. B. , Shchekin A. I. 
Published: October 2015

Abstract
This paper discusses a system approach to planning the development of multilayer offshore fields consisting of producing horizons with various types of reservoirs. The method is based on simultaneous analysis of seismic data, well logging and well testing results, field geophysical reservoir tests, well exploitation findings, and PVT analysis and detailed hydrodynamic field modeling. The model is developed consecutively and based on a "simple-to-complex" principle – from background data verification, application of the material balance method for estimating geological reserves and reservoir energy state, fault conductivity analysis, application of analytic and semianalytic methods for reservoir porosity and permeability calculations to development of a consistent hydrodynamic model as a basic tool for calculating various options of field development and selecting the optimal exploitation method with account for technical infrastructure limitations. As a result of works completed at an area of one of the biggest fields of the Socialist Republic of Vietnam, optimal positions for planned wells have been determined, a geological and technical action program has been developed, and a flooding pattern has been validated and arranged.
Digital and Automated Offset Well Analysis with Focus on the NCS
Authors: Mosesyan Mikhail A. , Surguchev Leonid M. , Mathisen Petter 
Published: October 2015

Abstract
The Norwegian Continental Shelf (NCS) consists of more than 6000 wells, where a great portion of the data is publicly available. In addition each and every operator holds its private data. When planning a new well, obtaining high quality reference data from comparable projects in the nearby area often becomes an issue of vital importance and part of the modern Well Delivery Process (WDP), named the offset analysis. Our work has been focusing on improving and on streamlining this part of the WDP.
Up until recently, offset well reference data analyses for wells drilled on NCS could only be performed by "manual" search in the Diskos or internal databases. With this work we attempted to bring to the fore how to increase efficiency by having all relevant data directly available to the end user. Combining different data formats, public and private, was the major challenge allowing quick and automated analyses. By developing a digital tool, the aim was to achieve significant savings in engineering man-hours not jeopardizing, but increasing an overall quality of the well delivery process. Additionally, the target was to measure how much time an engineer could save by skipping the manual part of the data gathering but rather using data that is logged and recorded during a standardized process.
Increased efficiency, cost reduction, proper contingency planning, and accurate consideration of uncertainties and project specific risks, not least the safety aspect, are among the key indicators of successful offset well analysis. The data has to be thoroughly calibrated and further analyzed to benefit the knowledge of the area, adjacent wells, equipment, casing desing and previous experiences. Previous data and experiences should first increase an overall understanding of upcoming project and secondly, fill the gaps in offset analysis. Having a system where all previous wells are quickly accessible and data as well as experiences saved and grouped by standardized formats, users' defined criteria will automatically allocate the most comparable and appropriate wells, thus not overseeing the most relevant data. Time is thus saved by eliminating manual search and the data quality is increased by incorporating quality check procedures.
Right decision making, given time constraints, cannot afford overseeing important information, thus data need to be quickly available, trustable and easily accessible for the user. By implementing automated quality check functionality, the data integrity is taken care of. By simultaneously gathering the data from several sources in one place, the user has improved access to all the information needed to make the right decision, the first time, and in a timely manner. With relevant and properly selected data, we can at last afford adequate analysis including stochastic modeling, thus finally approaching proper decision making with focus on uncertainty and randomness.
Real Options as a Tool for Arctic Offshore Fields Valuation and Project Management According IFRS 6
Authors: Pelmeneva A. A. , Talipova A. S. 
Published: October 2015

Abstract
Current processes of globalization and integration of the companies into the world economy necessitated the unification of financial reporting to the third parties and external users, its transparency and uniformity of financial calculations and calculation procedures.
International Financial Reporting Standards (IFRS) today play the role of a certain standard or an example of how international companies have to generate financial reports. This imposes certain obligations on the reporting procedure. Thus, on the one hand companies operate under strict rules of how and that they can be reported. On the other hand, oil and gas companies implement large risky projects, which feasibility evaluation is often difficult in the conditions of high risk and lack of the information. This situation is typical for offshore fields, particularly in the Arctic offshore, where the degree of exploration is extremely low.
The present article is concerned with the real options valuation of offshore fields in the Arctic. The main point of the article is an example of the subsequent correlation of the price value of the real options and possible costs for exploration and evaluation of the field resource potential in accordance with the principles of IFRS 6 – «Exploration for and Evaluation of Mineral Resources», an accounting standard that is core to the understanding of accounting in the mining and oil and gas industries. IFRS 6 includes modified impairment testing of exploration and evaluation assets and replaced several others international standards as IFRS 8, IFRS 16 and IFRS 36.
This approach allows us to demonstrate the applicabilityof ROV (Real Options Valuation) method and its application to offshore projects with a high degree of uncertainty, carried out at an early stage and, in particular, for the Arctic offshore projects. For illustrative purposes two possible deposits were taken on the shelf of the Barents Sea and the Kara Sea. For these two illustrative examples of the fields in the above sea waters in accordance with the climatic conditions, taking into account the current tax and investment regimes three types of option were designed: to stop the project, to delay the project and to expand the project.
The main purpose of this work is to show the applicability of various models of real options for offshore development projects through the examples in the Arctic seas at the stage of prospecting and exploration. There is also the objective to show how the techniques of project management can be agreed under the rules of reporting standards reporting for companies operating according to IFRS 6 standard.
Pilot Tests of New EOR Technologies for Heavy Oil Reservoirs
Authors: Altunina L. K. , Kuvshinov V. A. , Kuvshinov I. V. , Chertenkov M. V. , Ursegov S. O. 
Published: October 2015

Abstract
Thermal-steam stimulation (TSS) is considered as the most effective among all up-to-date methods for heavy oil production. However problem consists in lower coverage by steam injection and decreased TSS efficiency at later stage of the development. Paper presents the results of solving this problem by combining thermal-steam and physicochemical stimulations and using "cold" technologies involving thermotropic gel-forming and oil-displacing systems: gels increase reservoir coverage, whereas oil-displacing systems increase oil displacement.
In 2008-2013 172 wells were treated on the Permian-Carboniferous reservoir of high-viscosity oil in Usinsk oilfield using IPC SB RAS technologies. As a result the increase in oil production rate ranged of 3-24 ton/d per one well and incremental oil production amounted to 980 tons per one well treatment. It is promising to use integrated technologies alternating injection of steam, gel-forming and oil-displacing systems. They are commercially produced in Russia and China.
In 2014 to improve TSS efficiency pilot tests of new technologies were successfully carried out: using gelled system based on surfactants with controlled viscosity to increase simultaneously reservoir coverage and oil-displacement factor; using polymer gel-forming system – for selective water shutoff in production wells.
TSS is effective, but expensive method. It is promising to use "cold" technologies. To enhance oil recovery from high-viscosity reservoirs at 20-40 °С we propose to use gels and sols based on low temperature inorganic gel-forming system and oil-displacing alkaline and acid systems based on surfactants, inorganic buffer solution and polyol with controlled viscosity, from tens to hundreds mPa·s, and low freezing point, -20÷-60 °С. In 2014 pilot tests of new "cold" technologies were carried out in Usinsk oilfield. Alkaline system was injected into 5 and acid system into 10 low productivity production wells. After injections oil production rate increased by 5-15 ton/d, fluid flow rate increased by 15-25 m3/d. The technologies were recommended for commercial application.