bluuebunny/crossref_metadata_2025_split huggingface dataset:
Two-Way Coupled Geomechanical Analysis of Naturally Fractured Oil Reservoir's Behavior Using Finite Element Method
Authors: Dubinya N. , Lukin S. , Chebyshev I. 
Published: October 2015

Abstract
In this paper to the coupled hydrodynamic and geomechanical simulation is presented. The physical poroelastic problem is mathematically interpreted and is solved within numerical simulation of fluid flow in reservoir and corresponding deformation processes. Special theoretical methods and their implementation in practice are presented for the problem of geomechanical and filtration processes occurring in the case of naturally fractured medium. The proposed algorithm is realized via special software created within the study. The process of developing a three-dimensional numerical dynamical geomechanical model of oil and gas field characterized by naturally fractured rocks is considered. Effect of mechanical parameters on the production rates is analyzed using a set of computational models, the appropriate sections of oil and gas field. The effect of changes in the pore pressure on the collector conductivity and ultimately on the characteristics of the production well is investigated.
Integrated Approach To Modeling Naturally Fractured Carbonate Reservoirs
Authors: Ardislamova D. , Salimgareeva E. , Gallyamova D. 
Published: October 2015

Abstract
The paper discusses the problematics of choosing the approach to modeling naturally fractured reservoirs. Relevancy of this study is connected not only with the increasing number of oil fields characterized by naturally fractured reservoirs which are being brought into development but also with the complexity and diversity of solutions for geological and hydrodynamic modeling of natural fracture networks.
Modeling of naturally fractured reservoirs presents a challenging task due high heterogeneity of their porosities and permeabilities. There is no such thing as a classical oil field with natural fractures as any such field is unique both in terms of its geology and reservoir engineering issues.
The integrated approach to modeling naturally fractured reservoirs is presented as a case study of R. Trebsa oil field. The approach is based on combining reservoir characterization studies at different scale of investigation. Conductive properties of natural fractures are analyzed with the help of rock mechanics. Pore pressure influence on conductive properties of the system is also discussed.
The results of the modeling revealed that the integrated approach gives a robust and reliable representation of the system under the study. Estimation of in-situ stress influence on conductive properties is a valuable analytical tool which should be used in the framework of this approach. Dynamic simulations of the system behavior based on the discreet model are found to be very sensitive to compressibility. Thus, this parameter needs to be adequately defined. It is also demonstrated that when pressure declines the fracture permeability may significantly reduce due to compressibility.
The results of the study pave the way to more efficient field depletion strategies for fractured reservoirs, optimization of well patterns and more realistic and robust reservoir flow simulations.
Operational Decision Making Reaching New Frontiers with Real-Time Downhole Telemetry in the Russia's Arctic
Authors: Tanygin I. A. , Sherstobitov A. V. , Barylnik S. A. , Abramochkin S. A. , Davidovskiy A. O. , Belov M. V. , Zhandin A. O. 
Published: October 2015

Abstract
This paper presents the first experience of using a system for transmitting downhole data to surface (a telemetry system) based on wireless acoustic signal transmission during drill-stem testing (DST) in four carbonate reservoirs penetrated by an exploration well on Dolginskoye field in the Pechora Sea. Because no fluid would be recovered at surface during well testing, the job sequence program was optimized so that a full set of geological data could be obtained for each carbonate reservoirs in one trip.
The purpose of a wireless acoustic telemetry system is to provide a communication link between downhole and surface equipment by means of acoustic signals passing through the well testing bottom-hole assembly (BHA) and enabling a two-way communication channel to be established so that bottomhole data can be received on surface in real time, and downhole equipment can be monitored and controlled. The system allows operators to adjust the well testing program based on bottomhole pressure data and to check whether sufficient amount of data has been collected for the well testing objectives to be achieved.
Using a wireless acoustic telemetry system during dynamic well testing has many advantages compared to conventional testing with no downhole telemetry: bottomhole data can be received during job execution, operators have opportunity to monitor and analyze testing data and rely on a full set of representative data received in real time to make decisions for optimizing the job sequence program. The paper emphasizes the significance of receiving average formation pressure data during DST operations as it clarifies geological framework of the intervals under investigation and makes it possible to compare them with pressure data obtained by wireline tools when testing reservoirs with low porosity and permeability. The paper demonstrates a testing procedure optimization process which resulted in saving time on one well up to 36 hours and on other two wells – up to 24 and 48 hours, respectively, where acid treatments were considered unnecessary.
For the first time, dynamic well testing were completed on the Russian Arctic shelf in four carbonate reservoirs without any fluid recovery on surface, under an optimized testing program. Considering a short navigation season, this technology is ideal for real-time bottomhole data transmission applications.
Estimation of Safe Operation Life of Oil and Gas Wells Based on Examination of Production Casing and Borehole Annulus
Authors: Abakumov A. A. , Abakumov A. A. , Semin E. E. , Bazhenov V. V. , Mukhamadiev R. S. 
Published: October 2015

Abstract
The technology of well integrity evaluation has been developed and tested. The technology is based on magnetic introscopy equipment developed jointly by TATNEFT and Introsco Ltd. Present paper focuses on results of well integrity evaluations and provides requirements to the scope of data required to evaluate well integrity and the sequence of operations. Paper demonstrates the possibility of implementing the technology of well integrity evaluation in planning of workover operations.
Triple-Barrier Thickness Scanning Using Through-Tubing Pulse-Magnetic Logging Tool
Authors: Ansari Arsalan A. , Libdi Ziad , Khan Naeem , Aslanyan Arthur , Aslanyan Irina , Volkov Maxim , Arbuzov Andrey , Achkeev Andrey , Shnaib Fathi , Makhiyanov Ruslan 
Published: October 2015

Abstract
Servicing oil and gas wells requires their integrity assessment both during operation and before abandonment. One of the main objectives in well integrity analysis is the location of metal losses in tubing and/or casing caused by corrosion, erosion or other types of pipe damage. The first three metal barriers (normally tubing, production casing and intermediate casing) are of the most interest to the industry. Dual string completions is an additional complication to through-tubing assessment of the second and third barriers.
Magnetic Imaging Defectoscope (MID) is an electromagnetic scanning tool that recor
ds magnetisation decays induced by high-power electromagnetic pulses. Metal pipe barriers contribute to magnetisation decays at different times depending on their diameters, which makes it possible to differentiate each of them and determine their individual thicknesses. Thickness determination requires the numerical finite-element modelling of each recorded magnetisation decay and iterative fitting of the properties and thickness of every metal barrier to the actual tool readings. A data array can store hundreds of thousands decays, and the data processing optimisation loop therefore requires parallel computing with multi-core processors to process data within a reasonable time frame. The MID hardware and interpretation algorithm have been tested on multiple laboratory stands simulating various downhole multi-barrier completions from 2–7/8″ up to 13 3/8″ pipes with artificial defects of various shapes and sizes ranging from 7 mm to 140 mm.
This paper presents laboratory results and three selected field cases demonstrating the application of Magnetic Imaging Defectoscopy (MID) in single-string and dual-string completions for thickness evaluation of three barriers independently by a memory through-tubing survey.
Well W-01 with metal losses found at the same depth in the second and third barriers, i.e. 9 5/8″ and 13 3/8″ casings Well W-02 with metal loss found in the second barrier, i.e. 9 5/8″ casing, in an interval containing two strings. This corrosion has been confirmed by a repeated MID survey after pulling out the completion Well W-03 with through-hole metal loss found in the second and third barriers, i.e. large-diameter 9 5/8″ and 13 3/8″ casings, through a 7″ liner. This through-hole corrosion has been confirmed independently by High-Precision Temperature Logging and Spectral Noise Logging
The above metal losses have been located by through-tubing memory surveys in offshore wells that were to be abandoned. The results of the MID surveys were then used to design environmentally safe abandonment procedures.
Development of Integrated Modeling Tools for Field with SWAG
Authors: Efimov D. V. , Shlychkov K. E. , Vinogradov P. V. , Sergeev E. I. , Zaynulin A. V. , Dobrin V. K. , Savichev V. I. 
Published: October 2015

Abstract
The paper presents a case study from integrated modeling (IM) of R. Trebs oil field. The field development project assumes SWAG technology as the main production strategy. The gas for injection is planned to be sourced from R. Trebs and the adjacent A. Titov oil fields. Both fields are remote and located at a considerable distance from the existing infrastructure. Thus apart from enhancing oil recovery SWAG will also solve the problem of efficient use of the available gas resources.
The introduction of SWAG technology involves a number of engineering and operational challenges which need to be solved for its successful implementation. One of such tasks is designing the process flow structure of interconnected surface facilities: from the gathering system and treatment facilities to the pressure maintenance system. In this case material flows become conjugated, i.e. production rates affect injection rates which in their turn control the flow behavior of fluids in a reservoir. The produced associated petroleum gas after getting separated at the Central Processing Facility (CPF) and treated to the specified conditions is pumped into the pressure maintenance system to the well pads where after mixing with water it is injected back into the reservoir as a water and gas mixture.
The results of the study on the field characteristics as well as both surface and subsurface aspects of its development plan dictate the need for an integrated model in this project. This implies clearly set objectives and tasks for such integrated approach as formulated within the scope of this work. The workflow for integrated modeling is also developed with definition of requirements to the functionality and selection of tools for the realization of such model. Special emphasis is placed on the analysis of the requirements to the accuracy of the calculations and their efficiency with an effort to compromise the two.
These distinguishing features of the project are reflected in the developed integrated model. The paper describes the approaches to calculating various elements in the analytical model. Some of these algorithms have been modified to improve the accuracy of the calculations. The solution to the problem of history matching or calibrating the analytical model against the actual data is also discussed.
Utilization of associated petroleum gas at oil production facilities located in remote area for the generation of heat, electricity and synthetic liquid fuel
Authors: Buslaev George , Voloshchuk Yury , Baitalow Felix , Pardemann Robert , Meyer Bernd 
Published: October 2015

Abstract
The goal of this contribution is the introduction of a multinational research project aimed to the development of a novel concept for the utilization of associated petroleum gas (APG) using small-scale facilities located in remote areas in the Russian North. This project is funded by the ERA.Net RUS Plus program focused on the enhancement of the collaboration between European Union and Russia in the R&D area. It involves research institutions and companies from Russia, Germany and Poland and will be started in September 2015. The key step of the mentioned APG utilization route is the Syngas-to-Fuel (STF) process for the conversion of syngas into high-quality gasoline. One of the main challenges will be the selection of an appropriate technology for the syngas formation from APG, which is optimal adapted to the specific composition of APG usually containing (besides methane) higher hydrocarbons, CO2, N2, noble gases, sulfur-containing impurities, etc. The Russian-German-Polish project will be focused on the development of a comprehensive model for the overall process chain, including syngas generation, gas treatment, generation of heat and electricity, liquid fuels synthesis. Based on this model, technically viable and economically beneficial process integration schemes have to be defined taking into account the available infrastructure and the severe boundary conditions of the Russian North. For instance, a compact process design is desirable in terms of the reduction of capital costs. The final result of the ERA.Net RUS Plus project will be a technical and economical assessment of the novel technology for the APG utilization in remote areas, which is able to satisfy the needs of Russian oil and gas companies.
Selecting a Development System for Offshore Coastal Gas-Condensate Fields
Authors: Romanov A. S. , Buchinsky S. V. , Yushkov A. Yu. , Glumov D. N. , Voikov G. G. 
Published: October 2015

Abstract
A case study of a gas-condensate field located on the northeastern shelf of Sakhalin Island demonstrates the possibility of development of condensate-containing gas reserves by drilling very long ERD wells (drilling from the shore). The development system described in the paper includes drilling well with upward orientation. Such design provides complete cleaning of a wellbore from fluids and solids accumulated over a long period of maintenance-free operation. The choice of a development system using horizontal wells is also associated with the geological structure of the field (massive type accumulation with a single gas-bearing contour is broken by tectonic faults into separate blocks with different hypsometric elevations). Under the technical, economical (drilling from platform and from land, the use of subsea production systems, ice gouging with hummocks), and environmental (presence of valuable fish species in water areas and permanent residence of indigenous peoples) limitations, the development of individual wells with vertical completions turned out to be unprofitable. For the first time for this type of accumulation located in a coastal zone, a unique method of monitoring the recovery of reserves within the cross-section, as well as movement of the gas-water contact without the use of monitoring and pressure observation wells was suggested.
An Approach for Artificial Lift Applicability Maps Construction
Authors: Khabibullin R. A. , Krasnov V. A. 
Published: October 2015

Abstract
Using software for engineering calculations in oil production is a common practice. Wide spread software packages often focused on solving specific tasks - downhole equipment design, well performance analysis etc. Multiple wells calculations using standard software can be tricky. Moreover, visualization for multiple calculations results even trickier task with standard software.
A convenient way for presenting the results of the multiple calculations is construction of applicability maps. This paper discuss artificial lift technologies applicability maps construction. Applicability maps become useful for choosing lifting technique or analyze efficiency of current lift method in comparison with alternatives. It allows performing sensitivity analysis based on two most affecting on technology applicability parameters. In addition, maps can show technology applicability ranges which can be overlapped with production or forecast data.
The paper proposes a simplified method for constructing artificial lift (AL) applicability maps. It discusses natural flow, ESP and gas lift. Methods allows building maps on the fly, taking into account the main AL limitations with respect to multiphase flow and PVT properties. Case studies for Western Siberia fields in with AL applicability maps analysis discussed.
Prospects of Development of Jet Pump's Well Operation Technology in Russia
Authors: Drozdov A. N. , Drozdov N. A. 
Published: October 2015

Abstract
Oil production with submersible jet pump's installations can successfully solve many problems of well's operation in the complicated conditions. However, this technology, unfortunately, is not widely used in Russia. The purpose of this work is the study and improving of the oil production technology with jet pumps, and developing of recommendations for its effective application.
The analysis of the field experience of implementation has shown that, despite the achievements, the effectiveness of the known systems of oil jet pumps production is currently low.
To solve this problem, various methods have been developed.
One is the well operation with jet pumps driven by electric submersible pump (ESP), located in the bore pit, which is also the storage capacity and phase separator. The use of ESP, which is located in the bore pit, can significantly improve the reliability of the hydraulic drive of jet pumps in compare to the power plunger pumps.
It is necessary to achieve the best balance between ESP energy cost and efficiency of jet pumps. To optimize the system of oil production and achieve the highest efficiency of the jet operation of wells were developed methods and programs of software equipment selection and analysis, combined in a single software product. It allows select the most energy-efficient equipment and design the best system for the jet operation well cluster using ESP as a power unit deflated in bore pit. The developed method of jet pump selection and the calculation of ESP mode allows make a choice of the most suitable equipment for the jet operation of wells, including the power unit with the ESP and to increase the efficiency of the entire system.
There is another method of the technology of development, research and operation of complicated wells with jet pumps driven by the mobile power pumping complex.
Designed and manufactured mobile automated power station equipped with instruments to measure downhole pressures and temperatures, the operating fluid consumption and the well production rates. The station has successfully passed bench tests. The algorithms incorporated in this automated control system allow correctly handle the field information and set the optimal conditions of use.
A new technology has been suggested to use surface jet pumps for pumping out gas from the annulus and directing it with water into the injection wells. This technology is designed to increase oil production by reducing the annulus pressure and enhance oil recovery by SWAG injection.
Vulnerability of Arctic Coastal Environments to Oil Spill Impacts (White Sea Case Study)
Authors: Zagretdinova Dilyara R. 
Published: October 2015

Abstract
The abstract describes one possible approach to complex account environmental factors to determine the sensitivity of shoreline bays of the White Sea to the oil spill, proposed integral index of the sensitivity of coastal areas, taking into account the relationship of geological and geomorphological structure of the coast, the physical processes that occur in contact with the oil on shore and the vulnerability of biota to oil spills. The results of the practical implementation of the proposed approach and revealed the most stable and the most sensitive areas of the coastline of the Kandalaksha and Onega Bay of the White Sea.
The integrated vulnerability index portion is determined by summing the two components:
Vulnerability index components of the biota, in turn, defined as the sum of the biomass component of the biota ranged in a certain season, a factor of vulnerability of the component from exposure to oil spill (the latter was determined by expert assessment). Index ESI (Environmental Sensitivity Index), NOAA experts proposed in 1976, ESI allows typify the coast on a scale of 1 to 10, with the assignment of the appropriate category of sensitivity determined by the conditions and the duration of conservation of natural oil, wind and wave loading the coast, its geomorphological features and technical complexity of the cleaning oil. An analysis of the satellite imagery SPOT-4 in the visible range obtained data on 700 km of the coast of Bay of the White Sea, allocated 67 segments, differentiated by the two above indices. In ArcGIS environment built four integrated maps showing the sensitivity of the coasts in winter, spring, autumn and summer seasons.
In the project tree consists of the following layers: topographic base scale of 1: 25,000, the layers of hydrography, hypsometry, map the seasonal distribution of biomass components of biota and integral sensitivity maps coasts to oil spills. The study suggests that the coast of the Kandalaksha and Onega Bay of the White Sea over a large area have a relatively high index of sensitivity, which leads to the need for development and improvement plans LC, recycling technologies of oil pollution (mainly Ecobiotechnologies), methods of remote sensing, as well as the creation and expansion of the network of marine and coastal protected areas.
The novelty of the work is as follows:
Accounting for different responses to oil the various components of the biota; The approach to determining the sensitivity regarding the two main elements of the environment - geological and geomorphological base and biota;
It is worth noting the need to introduce in the index makrofitotsenoticheskoy components as well as the automation of the updating of the database project ArcGIS for constant updating sensitivity maps coasts.