bluuebunny/crossref_metadata_2025_split huggingface dataset:
Challenges of Welding in Arctic Areas
Authors: Gens Rouslan , Leconte Sébastien , Graindor Guillaume , Gaffard Vincent , Godinot Henri , Romazzotti Henri 
Published: October 2013

Abstract
The aim of this paper is to review the challenges of onshore and offshore welding operations in Arctic extreme environments in terms of: Health, Safety and Environment,Equipment exposure to cold environment,Logistics,Welding performance requirements: weld quality and productivity.
It lists the key elements to ensure successful onshore and offshore welding operations meeting both project productivity and quality targets in extreme cold areas.
Qualification of equipments either in cold chamber or in extreme cold conditions is a pre-requisite. It must be ensured that batteries, materials (metallic and non metallic), fluids (hydraulic and engine oils …) are suitable for the working conditions. Due to logistics issues, preventive maintenance on all equipments is very important before starting any operation.
Work organization is highly impacted by workers exposure to very low temperature. High performance protective clothes are helpful but harsh external conditions mainly promote the use of automated, reliable and high deposition rate welding processes.
Finally, welding quality is a major concern to avoid pipeline leak or failure in very sensitive environments with difficult access for emergency repairs. It relies on qualified welding procedures, a limited number of manual operations, narrow ranges of welding heat inputs, strictly controlled preheating conditions and real-time monitoring of welding parameters during operations.
The main contributions of this paper are: to list the most important parameters to make welding operations successful in Arctic extreme environments and to reduce logistics issues.to highlight the interest to use fully automated, versatile and compact (limited coating cut backs lengths) welding equipments in terms of welding crew requirements and operation time.to evidence how good low temperature properties (in particular impact properties) can be achieved on QT seamless and TMACC seam welded pipes throughout optimization of welding thermal cycles.
Arctic Offshore Pipeline Design and Installation Challenges
Authors: Paulin Mike 
Published: October 2013

Abstract
With the oil industry’s continued quest for oil and gas in frontier offshore locations, several developments have taken place in regions characterized by seasonal ice cover including the US Beaufort, North Caspian, and Sakhalin Island. In these projects, pipeline transportation systems have been used, which are a cost effective, safe and reliable mode of hydrocarbon transport to shore. Ice gouging is one of the key design issues that affect engineering considerations with respect to strain based design, target burial depth requirements, cost, and safety.
It is generally accepted that offshore pipelines in ice environments will need to be trenched and backfilled for protection. Burial depths can be greater than those that might normally be required for pipelines in temperate climates. Burial depth requirements will be a function of the design ice gouge depth (to prevent interaction between the ice and pipe) and an acceptable level of subgouge deformation beneath a gouging ice keel (which potentially strains the pipeline). There still exists uncertainty on the magnitude and extent of subgouge soil deformations due to ice gouging and the importance of sediment transport mechanisms for biasing gouge statistics.
Other challenges that must be considered include strudel and hydrodrnamic scour, thaw settlement and frost heave, and upheaval buckling. These considerations may also influence burial depth requirements.
Approach to Optimization of Acid Treatment in Oil Reservoirs
Authors: Volnov I. A. , Suchok S. N. , Obsharov P. A. 
Published: October 2013

Abstract
The mathematical model of two-phase displacement of oil by an acid aqueous solution in the neighborhood of a well and a hydraulic fracture [1] was used for investigation processes of optimization acidizing and acid fracturing. It takes into account the kinetics of acid dissolution of a carbonate rock. The proposed model allows us to improve the process of searching and selecting the best design for acidizing and acid fracturing.
The effect of well acidizing and acid fracturing are estimated. It is shown possibility to find the best value of such parameters as the speed of injection, speed of reaction and volume of acid mixture injected into a well during acidizing and acid fracturing. At given process parameters in the real case is shown importance of studying the process of interval treatment including the possibility of optimizing the design of each of the treated intervals.
The control of such parameters as the injection rate, the chemical reaction rate and the volume of injected acid makes possible to reach the maximum treatment effect at the given solution volume. Also calculations showed that in the case of the acid fracturing the significant slowing of the reaction rate may lead to large leakage of unreacted acid into the reservoir, extending the penetration zone, but also reducing the effects near the fracture and thus worsening the result of treatment.
The created model was applied to numerical calculations for real cases. Field and calculated data are in good agreement. Using of this approach allows us to find the ways for new possibilities in improving design of acid treatments and understand the current status of the proposed design.
Performance Evaluation of Gas Condensate Wells Treatment with LNG Rims and Dry Gas Displacement
Authors: Glumov D. N. , Reitblat E. A. , Buchinskiy S. V. 
Published: October 2013

ABSTRACT
The paper reviews the performance evaluation of measures against condensate banks in bottomhole zone. The study is based on compositional simulation. According to the results, optimal parameters for LNG injection and dry gas displacement in the formation are selected; duration of the measures taken and incremental recovery are evaluated.
Optimizing ESP Performance in the Kharyaga Field
Authors: Komova Tatyana , Falla Michel , Osipova Irina , Cuadros Ernesto , Shaikhutdinov Ruslan 
Published: October 2013

Abstract
Total E&P Russie (TEPR) has been operating in Kharyaga field in Komi Republic, Russia, since 1999 under a production sharing agreement (PSA) signed in 1995. Two oil-bearing carbonate reservoirs, Object 2 and Object 3, are produced under the terms of the PSA. The upper Object 3 is pressure supported by an active aquifer. The lower Object 2 was initially produced by depletion before initiating water injection to maintain pressure above bubble pressure. Most of the wells are unable to produce in natural flow and have to be activated. Primarily because of high H2S content, dissolved gas, and wax in the produced oil, well conditions in Kharyaga field are considered harsh for ESP operations. These conditions affected ESP performance and run life, causing premature ESP failures.
The project started in 1995 with the evaluation and completion of three existing wells in the Object 2 reservoir. These wells started producing under natural flow in 1999. The phase 2 drilling campaign started in 2001 and completed in 2007 with an increase of the well count by 10 producer and 3 injector wells. Because of reservoir depletion caused by existing production activities, all oil producers were equipped with electrical submersible pump (ESP) systems to help increase overall field production. The pressure support was provided by the adjacent water injector wells. In 2008, TEPR started the phase 3 drilling campaign, which is still ongoing. All 20 producers and 10 injectors drilled to date are equipped with Schlumberger ESPs.
Data comparing 2004 to the present shows drastic improvement of ESP performance as a result of the implementation of several ESP design modifications in combination with increased attention to ESP operational procedures and detailed analysis of downhole parameters. As a result of the mutual efforts from TEPR and Schlumberger, the ESP mean time between failures (MTBF) has increased by approximately three times with an overall increase in field production and a reduced number of workovers due to failed ESPs. The average run life of installed ESPs has increased to 1,052 days. Schlumberger has been the company’s supplier for ESP equipment, associated services, and maintenance since 2004, and, in July 2011, services were extended for an additional 3 years.
Optimization of Production Capacity for Oil Field in the Russian Arctic
Authors: Khasanov M. M. , Bakhitov R. R. , Sitnikov A. N. , Ushmaev O. S. , Dmitruk D. N. , Nekhaev S. A. 
Published: October 2013

Abstract
Oil field development in the Russian Arctic economically contrasts with projects in well developed oil regions. In developed regions (ad ex. West Siberia) considerable cost items are drilling and infield facilities (wellpads, gathering lines and etc.), but external transport infrastructure cost is negligeable. For a new region, especially for the Russian Arctic, cost of external infrastructure is significant. Infrastructure costs substantially affect plateau rate. It’s a common practice to cap oil production rate in order to reduce initial external infrastructure investments, but such effort simultaneously reduces discounted profit of a project. This paper analyses main cost drivers of an external infrastructure in Arctic and harsh environments. Infrastructure cost assessment based on its throughput capacity (maximum oil production rate) is discussed. We propose a method for economical optimization of oil production profile in Arctic environment in correspondence with tanker fleet characteristics.
The Technology of High-Performance Artificial-Lift Operation of Oil and Gas Wells in the Complicated Conditions of the Arctic Fields
Authors: Drozdov A. N. , Malyavko E. A. 
Published: October 2013

Abstract
In the fields of the Arctic region of Western Siberia, the operation of oil and gas wells is complicated by many factors. Among these problems, it should be noted low reservoir pressure and low rates during production of oil from reservoirs, low inflow rates of heavy oil, as well as the flooding of low-pressure gas wells leading to the well shutdown and the decrease of production.
The technology of artificial-lift operation with the electrical submersible plunger pump (PP) was developed for the low-flow-rate wells in the complicated conditions of the Arctic fields (Urengoyskoe, Yamburgskoe, Russkoe). The key elements of this technique are the linear motor with high-energy permanent magnets and plunger pump. Work on energy and structural optimization of the experimental unit allowed to minimize the steel intensity, to ensure ease of the operating, high reliability, ability of using in horizontal wells and the pressure independence on flow rate. The use of innovative single-wire system power of electric motor provides an opportunity to significantly reduce the cost of the electricity transmission by cable, as well as to reduce the thickness of the cable and improve the reliability of the system. One of the alternative technology involves the use of umbilical, which combines the functions of cable and tubing, and wellhead blow-out preventer (BOP). This technology allows operating wells by artificial-lift method without the well killing, as a consequence it reduces the time and maintenance costs of workover, increases the security of round-trips.
Theoretical calculations and studies confirm the efficiency of the chosen technical solutions that can provide cost-effective and energy-efficient artificial lift operation of oil and gas wells for the Arctic fields and other problem areas.
Relic Gas Hydrate and Possibility of their Existence in Permafrost within the South-Tambey Gas Field
Authors: Chuvilin E. M. , Tumskoy V. E. , Tipenko G. S. , Gavrilov A. V. , Bukhanov B. A. , Tkacheva E. V. , Audibert-Hayet A.. , Cauquil E.. 
Published: October 2013

Abstract
Isolated gas and gas hydrates in the permafrost are serious geological danger in the process of oil and gas field development in Arctic. The particular hazard is the largegas accumulations confined to the sand and loamy sand horizons in the permafrost at depths down to 200 meters. Such gas accumulations are found in a number of Yamal gas fields and South-Tambey gas field among them. There are some indirect signs that they may be relic gas hydrates formed earlier in specific hydrate accumulation conditions. Up now they might have been preserved in the permafrost due to the effect of gas hydrate self-preservation at temperatures below zero. These gas hydrates lying above the modern gas hydrate stability zone are in a metastable state and very sensitive to various anthropogenic influences. While drilling and during borehole operation of in the areas of relic gas hydrates locations various technical complications up to bow out may occur.
To evaluate the possibility of formation and existence of relic gas hydrates on the territory of the South-Tambey gas field the mathematical simulation and experimental modeling were performed. The aim of mathematical simulation was to understand the dynamic of the permafrost thickness and of the zone of gas hydrates stability (GHSZ) in the Late Pleistocene and Holocene. The simulation allow to present the evolution of the permafrost during which the zone of gas hydrates stability started from the earth’s surface being located within permafrost. As the permafrost has never fully thawed, near surface horizons may still contain relic gas hydrates to this day. Experimental researches were undertaken to study the possibilities of preservation of relic gas hydrates in the permafrost of the South-Tambey gas field up to now. The experiments consisted of two stages. The first part was the artificial saturation of field samples by methane hydrate. At the second stage we studied processes of self-preservation of pore gas hydrate in the frozen samples under nonequilibrium conditions close to the reservoir conditions such as temperatures –5…-6 0C and pressure of 0,6–1,3 MPa. These experiments highlignt the high stability of the pore gas hydrates in the frozen samples at the given nonequilibrium conditions.
In general we can make a conclusion that the existence of relic gas hydrates on the territory of the South-Tambey gas field at depths of less than 200 m in the permafrost is possible.
Coastal Dynamics Monitoring at the Barents and Kara Seas
Authors: Vergun Alexey , Baranskaya Alisa , Belova Nataliya , Kamalov Anatoly , Kokin Osip , Kuznetsov Dmitry , Shabanova Nataliya , Ogorodov Stanislav 
Published: October 2013

Abstract
Coastal dynamics monitoring on the key areas of oil and gas development at the Barents and Kara Seas has been carried out by Laboratory of Geoecology of the North at the Faculty of Geography (Lomonosov Moscow State University) together with Zubov State Oceanographic Institute (Russian Federal Service for Hydrometeorology and Environmental Monitoring) for more than 30 years. During this period, a unique monitoring technology, which includes direct field observations, remote sensing and numerical methods, has been developed. The dynamics of thermal-abrasion coasts are directly linked with climate and sea ice extent changes. We have also evaluated the influence of local anthropogenic impacts on the dynamics of the Arctic coasts. As a result, a method of forecasting the dynamics of thermal-erosion coasts taking into account climate changes has been developed.
The Integrated Assessment and Large-Scale Zoning of the North-Eastern Shelf of the Black Sea on the Geohazards
Authors: Mironyuk S.G.. G. 
Published: October 2013

Abstract
One of the most important tasks of research on the shelf is the evaluation of the sustainability of marine facilities within the subaqueous engineering-geological structures [32]. Among the geological hazards that may pose a threat of loss of stability of shelf platforms, pipelines and other objects underwater production are landslides, gravity flows, mud volcanic eruptions, liquefaction of soil under dynamic loads, etc. In order to prevent damage subaqueous techno sphere must perform assessment of geological hazards and to present the main results of this assessment in the form of predictive engineering-geological maps (maps of the geological hazard). [31]
To date, most of the developed approach the forecast regionalization of the territory by the degree of geological hazards are: method of estimating the parameters determining the intensity and destructive power of geological processes in the study area (areal damaging areas, frequency, speed the development process, etc.);assessment in concordance with natural and man-made factors-framwork influencing on the development of the processes of with segregation of some taxon on a score system;a method for prediction of geodynamic mapping (calculation of the geodynamic potential) on the direct manifestation of the processes and quantitative assessment the weight of factors affecting on the geohazards;expert assessment of the hazards of geological processes, phenomena and geological objects to the buildings and structures.
The basic principles of mapping marine geological hazards along the route of the pipeline "Dzhubga-Lazarevskoye-Sochi" (DLS) (commissioned in 2011) is expert assessment.
Software Development to Assess Seismic Resistance of Oil and Gas Complex Ground Facilities
Authors: Golubev Vasily , Petrov Igor , Khokhlov Nikolay 
Published: October 2013

Abstract
The goal of this article is the development of the research software for precise estimations of seismic resistance of ground facilities. The base of the method proposed is the mathematical modeling of elastic waves propagation originated in the earthquake hypocenter through heterogeneous media. As a source of the perturbation the geophysical focal mechanism model based on the slipping along the fault is used. For the description of dynamic behavior of media the hyperbolic system of equations of elastic media is used with the explicit allocation of contact borders of all heterogeneities. It is solved using the grid-characteristic method on curvilinear structured 3D meshes. One feature of used numerical algorithm is its high scalability per number of cores. The usage of curvilinear meshes allows description of a wide variety of geometries with high precision. Assessments of seismic resistance are based on the analysis of plasticity and rupture criteria (Mises, Tresca, etc.). Mathematical formulation of problem, development of the research software and a set of numerical experiments were done by authors. The results of modeling of propagation of seismic perturbation through geological multilayered medium and assessment of seismic resistivity of ground facility are described in this article. The estimation of software scalability per core was carried out. The wave response from a cluster of gas-filled vertical cracks was obtained in 3D case.
Cone Penetration Testing in Deepwater Barents Sea Regions: Field Operations, Data Processing and Interpretation
Authors: Manzhosov Sergey 
Published: October 2013

Abstract
Cone penetration testing (CPT) is one of the principal methods for the offshore geotechnical investigations worldwide and can rival drilling and coring in scope of field work. But, in the same time, CPT is not that widespread in Russian practice of the offshore geotechnical researches. Experience of execution of quite large amount of the offshore CPT in seabed mode is described in this article. Distinctive feature of the conducted field investigation is execution of the testing with heavy CPT rig from the vessel of opportunity. Aspects of vessel mobilization and field operations workflow considered in this article. Description of the data processing and interpretation is given. Typical geological cross section for investigated area is shown. Stratification of the soil profile was done using soil behavior types diagrams. Layers of soil are defined and characterized based on CPT data.
Emphasis is given to determination of undrained shear strength based on cone resistance data. Correlation is found between undrained shear strength measured in onboard laboratory with shear vane and in-situ measured cone resistance. Achieved results were compared to materials of other studies on same subject and recommendations of the Russian regulatory document. Generally good correlation was found.
Described approach to the offshore geotechnical investigation and technical solutions can be utilized for Arctic oil and gas fields development, where data for stratification and properties of soils are required. Derived correlations between undrained shear strength and cone resistance can be used for interpretation of CPT data of the future projects in Arctic regions.
Dual-Band Radar with a Radio Interferometric Channel for High-Accuracy Ice Situation Estimate
Authors: Isakov M.. , Smirnov E.. , Remishevsky A.. , Baskakov A.. 
Published: October 2013

Abstract
Fore remote monitoring of characteristics of sea arctic ice fields, such as speed and direction of ice motion, distance to an ice floe and thickness of ice, as have shown the conducted researches and the situation analysis, can be used radar system. Fore this purpose, we offered multiband multi-channel interferometric radar system that operates on two wavelengths (3 cm and 8,6 mm). The radar system is design to use pulse (with wide bandwidth) compression techniques, coherent integration and interferometric processing to obtain high loop sensitivity and high resolution on speed, range and altitude. This paper will focus on an estimation of a relief of ice fields by an interferometric method.
The Oil and Gas Industry’s Commitment to Responsible Arctic Operations: An Innovative Arctic Oil Spill Response Technology - Joint Industry Programme
Authors: Mullin Joseph 
Published: October 2013

Abstract
There have been many large-scale tests going back decades on recovery of oil in ice in the autumn and winter months in the Arctic and through this research and development the Industry has developed the equipment and tools to respond in Arctic conditions. To further build on existing research and improve the technologies and methodologies for Arctic oil spill response, nine oil and gas companies (BP, Chevron, ConocoPhillips, Eni, ExxonMobil, North Caspian Operating Company, Shell, Statoil, and Total) established the Arctic Oil Spill Response Technology Joint Industry Programme (JIP). The goal of the JIP is to advance Arctic oil spill response strategies and equipment as well as to increase understanding of potential impacts of oil on the Arctic marine environment. The programme is coordinated by an Executive Steering Committee comprising representatives from each company. The International Association of Oil and Gas Producers (OGP) is providing project management expertise and industry experts/ scientific institutions are being engaged to perform the scientific research.
Over the course of the programme, the JIP aims to deliver new capability in the following six areas (dispersants, environmental effects, trajectory modelling, remote sensing, mechanical recovery, and in situ burning (ISB)).The JIP will also explore opportunities to conduct field experiments to verify research results. Today, twelve projects are in progress ranging from dispersant effectiveness testing, modelling the fate of dispersed oil in ice, assessing the environmental effects of an Arctic oil spill, advancing oil spill modelling trajectory capabilities in ice, extending the capability to detect and map oil in darkness, low visibility, in and under ice, improving efficiency of mechanical recovery equipment in ice, to detailing the large body of knowledge that already exists on ISB, and expanding the ‘window of opportunity’ for ISB response operations. This paper presents the progress to date in the Arctic JIP.