bluuebunny/crossref_metadata_2025_split huggingface dataset:
Hydrocarbon Potential Of The Enisei-Khatangsk Region With In The Taimyr Autonomous District (TAD) And The Extent Of Its Development
Authors: Dmitrievsky A. N. , Eremin N. A. , Shabalin N. A. 
Published: October 2013

Summary
The geological studies carried out on the territory of the Taimyr autonomous district of the Krasnoyarsk Krai during the period of 1930–1950 by the Glavsevmorputi subdivisions, the USSR Mingeo organizations and the institutes of the USSR Academy of Sciences (AS) show a considerable thickness of sedimentary deposits perspective for oil and gas, the availability of the Paleozoic salt-bearing sections, the prolongation of the continental tectonic structures into the water area of the marginal seas followed by the increase of the sedimentary deposits The TAD borders on three oil and gas bearing provinces of Siberia such as the West-Siberian, the Khatango-Vilyuisk and the Leno-Tungussk the limits of which allocate the Enisei-Khatangsk OGR and partially the Pur – Tazovsk OGR. (20). The total area of the oil and gas potential lands is over 550 th square km (13).
Cost Efficient Decrease Of Risks Due To Additional Geological Information
Authors: Balaban I. J. , Gutman I. S. 
Published: October 2013

AbstractThe paper presents methods for the economic evaluation of additional geological information obtained through a variety of field-geological studies in the presence of geological risks. This is particularly important in the Arctic where the risks associated with the development of hydrocarbons are extremely high. The evaluation is based on the ability to make the right decision that is reduced to the choice of two options: to continue the project or abandon it. We consider Monte Carlo method for economic evaluation of the information. The paper also suggests to express the economic effect of information in equivalent amounts of hydrocarbons instead of monetary units. This in some cases will greatly simplify the calculations using practical formulas to estimate the economic impact of additional information based on fairly standard data available to the companies.
Influence of Permafrost on Seismic Imaging in Alaska
Authors: Matson Rick , Wolf Kevin , Yancey Daniel 
Published: October 2013

Abstract
A layer of permafrost, approximately 500m thick, lies immediately beneath the surface of Arctic Alaska’s Central North Slope. This frozen layer of unusually high seismic velocity overlies more than twenty producing fields containing over 60 Billion in place barrels of light and heavy oil. Multiple reservoir levels ranging in depth from 1000m to 3000m are nominally imaged using conventional surface 3D seismic technologies. Natural arctic surface features and man-made sub-surface activities produce local bodies of unfrozen sediment with anomalously low velocity in the surrounding high velocity permafrost. Abrupt lateral and vertical velocity variations detrimentally affect the conventional surface seismic image at reservoir depths, thereby negatively impacting our ability to describe the reservoirs and maximize production of this vast resource.
BP-Alaska, as operator of many of these fields, is motivated to apply optimal seismic acquisition and processing techniques to minimize permafrost-related image distortions. We are therefore developing a permafrost velocity characterization of both the offshore and onshore environments on the Arctic Central North Slope to guide the appraisal of available geophysical techniques. Our characterization is underpinned by: 1) physical properties of frozen and unfrozen sediments taken from the literature, 2) regional and local morphologies of the permafrost based on well log measurements, 3) the application of numerous geophysical techniques for the widespread measurement of shallow (upper 600m) velocities, and 4) a dynamic model for thawing of the permafrost caused by either naturally occurring or man-made circumstances to help predict the extent, shape, and depth of local velocity anomalies.
BP-Alaska is making progress in understanding the permafrost velocity field on the Central North Slope; but gaps in our ability to characterize a large portion of the permafrost interval still persist. Some techniques show promise but may not be economic in a brown field business environment located in an arctic acquisition environment.
Integration of a Complex Log Data Suite for the Evaluation of Pokurskaya Formation in Western Siberia
Authors: Ezersky D.. , Vishnevskaya I.. , Tukhtaev R.. , Charupa M.. , Latypov A.. , Weinheber P.. , Bikeev E.. , Pasynkov A.. , Tikhomirov E.. 
Published: October 2013

Abstract
The maintenance of Western Siberia oil production levels has required the industry to evaluate and develop ever more complex reservoirs. In this case study we look at the evaluation of the heavy oil bearing field located in the north part of Western Siberia and specifically the unconsolidated Pokurskaya formation of the Cenomanian age. The specific evaluation requirements included an understanding of the oil properties, especially viscosity and its variations, and an understanding of recovery factor by an analysis of residual oil saturation. In order to accomplish these objectives an extensive suite of log data as acquired including standard triple combo data, cross-dipole acoustic, NMR, micro-images, spectroscopy and formation tester samples and pressures.
In this paper we show how an innovative use of NMR data allowed us to improve the fluid model and irreducible water saturation calculations. Combining NMR with standard data allowed a prediction of the residual oil saturation. Additionally, from the NMR data we were also able to extract oil viscosity information, however we needed a calibration point and for that a formation oil sample was required.
Unconsolidated formations saturated with viscous oils are notoriously difficult to sample with formation testers. Sand production can lead to contaminated samples, tool plugging and even borehole collapse. To avoid these issues we included dipole sonic data to estimate formation strength in order to select the optimal sampling locations. Additionally a new ‘dual intake’ straddle packer configuration was used to optimize the fluid sampling. As a result of these precautions samples were successfully acquired and the resulting PVT data was used in field development planning as well as calibration points for a continuous NMR-derived viscosity curve.
Engineering Protection for Permanent Offshore Platform against Ice Impact in the Arctic Shelf
Authors: Kutvitskaya N. B. , Ryazanov A. V. 
Published: October 2013

Abstract
Construction solutions, construction technology and exploitation conditions of protection facilities, keeping the floating platforms at a designed location, are proposed in this scientific paper. They have been developed and proved by thermal calculation and strength prediction.
Protection structure includes a pile row, made of metal pipes, and special all-year cooling (freezing) devices, located inside the metal pipes. The piles are installed into the sea floor sediments or on the bedrock, depending on soil conditions. A compressor unit runs the cooling system during the construction on floating platform. The agent inside the cooling system is circulating which causes ice (in water) and ice-ground (below sea bottom) cylinders to grow around pipes. Ice cylinders form piles of big diameter. These piles may interlock fully or partially, forming a shockproof wall, which can withstand ice loads.
Optimizing Underground Thermal Reserves By Insulating The Wellbore Monitoring And Modeling Wellbore Temperature In The Kharyaga Field’s Arctic Tundra Environment
Authors: Danquigny J.. , Semenov A.. , Eropkin E.. 
Published: October 2013

Abstract
The Kharyaga oil field is located beyond the polar circle in northeastern Europe, and since 1999, has needed first-class thermal insulation for its ESP-lifted wells to produce. In these Arctic conditions, the permafrost typically reaches thickness of up to 300 meters. And with the wax appearance temperature (WAT) or pour point as high as 50°C and 30°C for some geological objects, managing wells in order to minimize wax scraping operations is a real challenge. Especially during shut-in periods, as the produced fluids cool down the risk of wax totally plugging the tubing is significant.
To combat that risk, the production or injection annuli are systematically filled with gelled diesel. Permanent real-time temperature monitoring by fiber optic sensors has been deployed in the production annulus of six wells so far, to measure temperature distribution along the wellbore across the permafrost layer, down to the reservoir. And thermal modeling, using the Enthalpy Balance thermal model, shows a good match with the temperatures thus measured. It also confirms the fine thermal quality, as per expectations, of the gel deployed.
For the purposes of further development of the Kharyaga field, which includes wells with liquid expected rates less than 1,000 bpd, well modeling flags up the necessity for additional thermal insulation. Using 3½" instead of 4½" tubing is a first solution: trials on two wells have shown a gain of up to 12°C. The benefit and design of field proven double-wall tubing was also assessed for the many additional development producers planned. One set of vacuum-insulated tubing (double-wall tubing with vacuum inside) is already on the spot ready for a field trial on a future work-over in the Kharyaga environment.
Environmentally Compatible Drilling Fluids
Authors: Pilgun Sergei , Aramelev Aleksey 
Published: October 2013

Abstract
Well drilling under arctic conditions affects the ecological situation in the region. At the same time, specific climatic conditions have additional requirements for designing, equipments and technologies. There are also particular specifications for drilling highly tortuous offshore wells. Making drilling fluids is a main task to ensure both technical capability and safety in case of oil spill.
The Arctic Region is the world storage of energetical reserves. Significance of offshore mining is increasing from day to day, especially on the background of depletion of easily accessible hydrocarbon reserves. Exploration of a shelf plate is an essential component of economic and strategic development of Russia.
Shelf plate exploration is carried out under harsh weather conditions: vast time period of storms, hard ice situation, change of stream velocities. All this creates additional requirements for the design, choice of applied equipment and technologies. Well drilling under arctic conditions is relevant to the environmental safety in the region. Restoration of the ecological balance in the zone of ecological catastrophe takes a lot of time. And major disasters are capable to tilt the ecological balance of our planet at all.
The main objective of exploration of the arctic shelf plate is development and implementation of high performance technologies that are security-wise and applicable to use in the Arctic region.
The important link of the technological chain of modern well construction is the drilling fluid that performs a lot of functions when carrying out drilling operations.
Improved Geomagnetic Referencing in the Arctic Environment
Authors: Poedjono Benny , Beck Nathan , Buchanan Andrew , Borri Luca , Maus Stefan , Finn Carol A. , Worthington E. William , White Tim 
Published: October 2013

Abstract
Geomagnetic referencing uses the Earth’s magnetic field to determine accurate wellbore positioning essential for success in today’s complex drilling programs, either as an alternative or a complement to north-seeking gyroscopic referencing. However, fluctuations in the geomagnetic field, especially at high latitudes, make the application of geomagnetic referencing in those areas more challenging. Precise crustal mapping and the monitoring of real-time variations by nearby magnetic observatories is crucial to achieving the required geomagnetic referencing accuracy. The Deadhorse Magnetic Observatory (DED), located at Prudhoe Bay, Alaska, has already played a vital role in the success of several commercial ventures in the area, providing essential, accurate, real-time data to the oilfield drilling industry. Geomagnetic referencing is enhanced with real-time data from DED and other observatories, and has been successfully used for accurate wellbore positioning. The availability of real-time geomagnetic measurements leads to significant cost and time savings in wellbore surveying, improving accuracy and alleviating the need for more expensive surveying techniques. The correct implementation of geomagnetic referencing is particularly critical as we approach the increased activity associated with the upcoming maximum of the 11-year solar cycle. The DED observatory further provides an important service to scientific communities engaged in studies of ionospheric, magnetospheric and space weather phenomena.
Solid Polymer Prevents Gas Migration into Cement Slurry in Subzero Conditions
Authors: Isgenderov Islam , Bogaerts Martijn , Docherty Kevin , Osayande Victor , Kanahuati Alia Iza 
Published: October 2013

Abstract
Cementing formations with medium to high gas migration severity in cold conditions is considered a very challenging operation for major operators in Turkmenistan. The liquid gas migration agents used in Turkmenistan for the above mentioned severities incur additional operational and technical challenges, particularly during the winter months as the ambient temperature falls below zero. In addition to the climatic challenges, Turkmenistan drilling activity often encounters the additional challenges of high pressures and narrow pore / frac windows.
This paper focuses on case studies to analyze the application of both liquid and solid gas migration prevention additives compared with conventional slurry systems in overcoming challenges encountered while cementing across gas bearing formations. To address such challenges, a solid polymer gas migration prevention additive has been field tested successfully in environments such as Canada, USA and Russia having similar conditions as Turkmenistan. A description is then given of a successful method of combining a special solid polymer based gas migration prevention system with good cementing practices, in order to not only achieve the primary objective of the cementing operation, but also yield improved logistics in terms of storage, handling, and no associated mix fluid aging or detrimental effect of thawing. Field case histories are presented, illustrating the versatility of the system in solving gas migration problems in seasonal climate changes.
Above all, solid gas migration prevention polymers are considered the best cost effective solution compared to the liquid gas migration agents of the same family which is considered as the key value for commercial oil and gas production.
Technology of Productive Horizons Casing Perforation by Drilling of Branched Channels With Midget Diameter and Curvature Radius
Authors: Aleksandrovich Lyagov Ilya , Aleksandrovich Lyagov Marina 
Published: October 2013

Abstract
Maintaining a high level of production volume means the maximum use of the opportunities of each well. The application of a number of ways to intensify well productivity, such as hydraulic fracturing, acid treatment, heat treatment, etc. is not always possible due to a number of geological and technological reasons. In addition, each of these methods has a negative component effect on the reservoir properties. The effectiveness of these methods, the impact on the bottom zone (producing zone) is often limited by the lack of reliable hydrodynamic connection between wells producing formation, which may be caused by deterioration of reservoir properties over time, the lack rock permeability, reservoir heterogeneity, insufficient length of perforations, etc. [1].
The new technology is designed to increase the perforation production flow rates and increase injection capacity of injection wells (by increasing filtration area producing zone), reduce water cut (by reducing the drawdown), as well as improving the turnaround time for well operation (by increasing the hydraulic perfection of producing zone) [2].
The technology involves the removal of the casing of the first stage of research and development project (hereinafter – drilling through the casing with change bit without lifting oriented capture and anchors for drilling in rock shown in Figure 2. The extension of the main trunk, injecting insulating special gelling agent, the creation of cement plug, drilling out its auxiliary barrel, drilling super long channels according to the predicted trajectory in one run [2, 3, 6].
Increasing the Frost- Resisting Properties of Cement Stone in Casing and Cementing of Wells Through the Use of Magnesia Cement Material
Authors: Pastuhov A. M. , Tolkachev G. M. , Kozlov A. S. , Anisimova A. V. 
Published: October 2013

Abstract
In 2012 by request of JSC"TNK-BP Management", in the Scientific laboratory "Technological liquids for well drilling and casing" of the Perm National Research Polytechnic University (PNRPU) works on assessing the properties of the cement materials developed by three foreign and one Russian service companies were carried out. These blends were announced as the cementing materials that had been specially designed for oil and gas well casing and cementing in the areas of Western Siberia and the Far North, where the presence of permafrost (PFR) in well profiles have made their use more complicated. The received testing results of the presented cement slurry – stone indicate that the signs of failure in the samples being tested for frost resistance are first indicated after 2 to 4 cycles of freezing and thawing. The samples showed fractures, flaking or chipping off. The maximum number of the "freeze and thaw" cycles prior to decreasing of cement stone strenght in the most frost-resistant of the blends presented for testing was 5, which is not enough to be able to predict a long-term integrity of cement stone incorporated in casing and cementing of the well.
To increase the quality of casing cementing within the intervals of permafrost rock formation, the employees of the PNRPU developed a new cementing blend with higher frost-resistance properties of cement stone. This special cement material is based on a highly active cementitious agent – magnesium oxide. The major advantage of this newly designed magnesia cement slurry is the higher frost resisting ability of cement stone as compared to those being tested. The reason for this is low capillary fluid content. The cement stone in such cementing material endures over 15 cycles of the "freeze" and "thaw" test. Among the positive characteristics of the cement slurry-stone which is viewed as perspective when used for casing cementing in the continuous permafrost zones are as follows: –possibility to achieve a lightweight cement slurry;–zero ice-thawing during putting the slurry into casing string annulus;–low rates on water separation and cement-water sedimentation of cement slurry;–good harden ability of cement slurry and strength development of cement stone at lower temperature;–adhesive bond formation between cement stone and ice.
The achieved magnesia cement blend can be used for experimental and industrial testing during casing cementing, when the casing strings extend through the perennially frozen rock deposits.
Improving Multistation Analysis of MWD Directional Magnetic Surveys
Authors: Bulychenkov Konstantin 
Published: October 2013

AbstractMultistation analysis (MSA) is a technique widely used in the industry to correct systematic errors of magnetic MWD surveys associated with drillstring interference (DSI). However, to ensure an acceptable uncertainty of the correction we must understand the geomagnetic reference accuracy.One of the main problems for magnetic MWD surveys is that the inaccuracy of the BGGM (BGS Global Geomagnetic Model) from the British Geological Survey (BGS), does not allow for correction of axial DSI for wells with inclination more than 55° in the west/east direction by the MSA method. If there is a local magnetic reference error, the BGGM does not have the required resolution to map it. This may mean that the azimuth error from the MSA correction will be significantly greater than the error caused by DSI. Thus, both a compensation for DSI and a good magnetic reference value are required to accurately position wells with MWD tools.A modification of the MSA algorithm uses a model of distortion caused by DSI when a trajectory deviates. Within residual uncertainty, the results thus calculated are combined with the conventional MSA. That allows the possibility of avoiding the current limitation of DSI correction uncertainty.The described algorithm avoids errors caused by geomagnetic reference inaccuracy in the case of a trajectory with changing direction and inclination. For cases with enough variation of the trajectory, we can correct axial DSI for horizontal wells in the west/east direction with high accuracy. Also, the method can be used for calculation of actual reference offsets from values derived from a geomagnetic model like the BGGM.The developed method is an evolution of MSA that keeps all the advantages of the conventional method and avoids the limitation caused by geomagnetic reference inaccuracy. Application of this algorithm is most beneficial in regions where BGGM accuracy is low, as it is in Russia. In addition, the method allows greatly improving the correction of surveys for horizontal wells near an east/west direction in the case of a deviated trajectory.
Choosing Oil Spill Response Method to Protect Sensitive Coastal Areas in the Russian Arctic
Authors: Belkina Natalia 
Published: October 2013

Abstract
Once oil has been spilled, urgent decisions need to be made concerning response options, so that environmental impacts are kept to the minimum. Options for protection of shorelines include containment and recovery, in-situ burning, use of dispersants or just leaving the oil to dissipate and degrade naturally. All response options have both limitations and benefits which need to be compared with each other. This process is known as Net Environmental Benefit Analysis (NEBA).
A NEBA for protection of coastal areas in the Russian part of the Barents Sea and the White Sea was performed by Ramboll in the framework of the UNEP/GEF project "Improvement of the emergency oil spill response system under the Arctic conditions for protection of sensitive coastal areas (case study: the Barents and the White seas)". The analysis was based on the results from modeling of spills of oil and oil products which are transported through the Barents and the White seas, oil spill sensitivity mapping as well as assessment of available oil spill response (OSR) resources in the region.
The analysis shows that coastline protection methods such as using dispersants or in-situ burning lack methodological and regulatory framework and at the moment they cannot be used in the Russian part of the Barents Sea and the White Sea. The optimal available technique in case of a spill of fuel oil or crude oil will be mechanical containment and recovery (use of booms and skimmers). However, mechanical methods will be both inefficient and extremely hazardous to combat spills of gas condensate or naphtha due to high explosion and fire risk until full evaporation of the volatile fractions has taken place. In such a case it is recommended to observe the slicks and await natural dissipation.
Challenging logistics in the region and harsh climatic conditions can significantly impede timely response to offshore oil spills and use of traditional mechanical recovery that creates need for adapting alternative tactics such as in-situ burning and dispersants.