bluuebunny/crossref_metadata_2025_split huggingface dataset:
Criteria and Techniques of Waterflooding Adjustment for Brownfield
Authors: Galeev Denis , Dadalko Roman , Potapov Alexander 
Published: September 2014

Abstract
The issue of waterflood control for fields in the 4th stage of development is analyzed. Generation of a wellwork program is based on the proposed method of integration of classical engineering methods and three-dimensional flow simulation. The results of the study allow to assess the current performance of oil-water displacement, to predict the profile of engineering parameters, and to form a targeted strategy to adjust the waterflooding system of an oil reservoir. The case study of a Western Siberia field is discussed, the deficiencies of the current development scheme are revealed, and measures to increase efficiency are presented in the form of both increased oil recovery and reduced volumes of produced and injected water.
ESP Monitoring and Control System Implementation in Western Siberia Brownfield
Authors: Haberer Sven , Krasikov Anatoly , Lavrinenko Andrey 
Published: September 2014

Abstract
To improve production in a partly depleted western Siberia brownfield, the field was partly upgraded using digital oil field technology to monitor and analyze electric submersible pump (ESP) conditions. The data from downhole and surface sensors was transmitted in real time to a central server and analyzed using modelling and diagnostic software. The results of this analysis enabled the ESP experts, located in the control center, to detect anomalies and prevent potential failures – as well as to remotely adjust the operating points of the ESP to optimize production. Wells monitored using this system showed a significantly increased ESP run life compared to ESP run life before implementation of this system, increasing the productivity of the field despite harsh operating conditions and the remote location. This paper discusses the results and lessons learned during the first phase of the project as well as the next steps planned.
The Study of Remaining Oil Location in Multi-Pores at Micro and Nano Scale
Authors: Yang Shu , Dong Pingchuan , Cai Zhenzhong , Ji Xiaoyu , Lei Gang , Wu Zisen , Dong Ruitao , Zhang Zhenghong 
Published: September 2014

Abstract
This paper analyzes pore-throat geometry characterization using 2D micro-CT and field scanning rock images of Tarim basin sandstone and presents the oil droplet flow model in real pore-throat network based on Navier-Stokes equations and Finite Element discretization to study remaining oil location at micro and nano scale.
Using the Gray-Level Histograms and mathematical morphology, the real pore-throat geometry network characterization is extracted from images as logic matrixes using our imaging progressing program. The porosity, pore-throat radius and representative elementary unit are calculated to the simulation model. According to the result of pore-throat network at micro and nano scale, the pore-throat hybrid grid model and the two-phase simulation are built up. It includes the continuous water phase and the single oil droplet. Furthermore, the study takes the additional resistance caused by capillary pressure, shear stress caused by boundary effects and droplets breakup model into consideration. The simulation is verified by an accuracy of approximately 20% with the experiment results. This paper is aim to predict the remaining oil location under different pressure differences and oil drop radiuses, and study the influence of these factors by the analysis of calculated oil droplet concentration and fluid streamline of the simulation.
The paper reveals the vortex flow exists in the pore-throat network and the remaining oil is likely to gather in the high tortuosity and strong vortex regions, especially at the edge of pores connected to the outlet branch throats, dead pores and the center of pores. In addition, the paper shows as the oil droplet size and pressure difference increase, the displacement efficiency decrease and the remaining oil concentration change. Overall this paper provides a fast methodology for pore-throat geometry characterization quantitative study and a pore-scale oil droplet flow model to predict remaining oil location under different conditions.
Saturation Evaluation of Low Permeability Condensate Reservoirs in the Presence of an Oil-Rim with Wireline Formation Testers
Authors: Novikov S. , Weinheber P. , Charupa M. , Rudenko D. , Filimonov A. , Blinov V. , Yazkov A. , Shadchnev N. , Milushkin A. , Piana M. 
Published: September 2014

Abstract
The determination of saturation and therefore fluid contacts can be challenging in certain low permeability reservoirs of the Yamal peninsula. The low water salinity and high shale content make contact determination with traditional petrophysical methods difficult. The low permeability also complicates contact determination using pressure gradient analysis. Downhole fluid analysis seems a logical choice, but it too is fraught with difficulties in low perm, near saturated reservoirs.
In this paper we show how to apply DFA for contact determination and how to mitigate, by interpretation and hardware configuration, the various challenges. Additionally we investigate the quality of the obtained samples with respect to their suitability for PVT studies.
Oil in Non-Conventional Reservoirs of Tatarstan
Authors: Khisamov R. S. , Bazarevskaya V. G. , Timirov D. A. , Bazarevskaya N. I. 
Published: September 2014

Abstract
This paper presents the results of research programs performed by OAO TATNEFT aimed at additions to reserves and increased production from non-conventional reservoirs found in Tatarstan. It is worth mentioning that TATNEFT has been studying non-conventional reservoirs since 1950s.
To date, most of Tatarstan's oil fields have entered their closing stage of development with 86% cumulative production of OOIP and increase of hard-to-recover reserves share from 33% to 80%. A considerable part (36%) of TATNEFT hard-to-recover reserves falls on carbonate low-permeability sediments with low-thickness fractured reservoirs.
Aiming at study of shale, or tight, oil in the territory of Tatarstan, TATNEFT has concentrated its efforts on the search for oil accumulations and study of low-permeability reservoirs and source rocks in the Tournaisian-Sargaevian formations.
Prospecting of nonconventional hydrocarbon reserves and nonconventional reservoir study is a challenging, still, a very promising line of activity associated that can add value and yield good returns, considering that the Tournaisian-Sargaevian formations are widespread in Tatarstan, the domanikites are source rocks with high organic matter content, and proved oil potential of these deposits.
A certain tight oil potential is also associated with the Samara, Ulyanovsk, Orenburg, Nenets Autonomous District, and Kalmykia leases. It is worth mentioning that evaluation of shale plays is not based on conventional methods involving seismic survey, logging etc., but rather on analysis of chemical-mineralogical and mechanical rock properties.
Analysis of available well data has been performed; underway are large-scale core recovery projects, including oriented core and quick capture. Considering geologic environment of the domanikites and the domanikoids in the Volga-Ural oil-and-gas province, petrophysical properties of these rocks, fluid composition and properties, G&G information is analyzed to design hydraulic fracturing treatment in wells targeting the domanikites and the domanikoids. Candidates for hydrofrac jobs have been selected. Dedicated drilling and reservoir management technologies are developed.
Vertical and Horizontal Integration to Overcome Extreme Operational Challenges for the Achimov Tight, Gas-Condensate Formation
Authors: Graf Thomas 
Published: September 2014

Abstract
The production focus has shifted from the easy-to-access, shallow, gas-bearing deposits in the Cenomanian and Valanginian of the Urengoyskoye Field to the deeper, tight, gas-condensate formations in the Achimov. Several different operators have started to develop the Achimov formation with different development strategies on over eleven license blocks; however, with the common objective to maximize liquid and gas production from their license. Based on a couple of pilot projects with extensive testing, a unified development plan over the entire Achimov formation had been devised before the development start-up to guarantee hydro-carbon recovery and guide the operators through the development. Due to the enormous challenges encountered in the Achimov formation such as high pressure, low formation quality and deviated well stability challenges, the initial unified development plan foresaw the drilling of simple production pattern with a large amount of vertical wells. However, since the instigation of the unified strategy, the technology has advanced to overcome most of the challenges encountered in the Achimov formation with the potential of improving the sub-optimal, original development plan.
This paper discusses the general challenges of the Achimov development from well construction, production operations to reservoir management encountered by the various operators and attempts to define integrated solutions chains to overcome those. The operational and financial impact of the various technologies of the solution chains is defined and a possible roadmap for field development is devised. Several different operators have started to develop the Achimov formation with different development strategies on over eleven license blocks.
Single-Size-Ball Interventionless Multi-Stage Stimulation System Improves Stimulated Reservoir Volume and Eliminates Milling Requirements: Case Studies
Authors: Yuan Feng , Blanton Eric , Inglesfield Jamie 
Published: September 2014

Abstract
In the last decade, there has been a tremendous growth in multi-stage fracturing for unconventional plays employing stimulation sleeves with open hole (OH) packers or cementing. Standard ball-activated frac sleeve systems with graduated ball seats have primarily been used because they can significantly save completion time and cost by facilitating the performance of multiple stimulations in a single continuous process compared with the conventional Plug and Perforate (P-n-P). However, traditional ball-activated frac sleeves have limitations in the number of stages that can be handled, the pressure drop and friction loss each one creates and the need to mill through the ball seats after stimulation. As the number of frac stages increases, the ball seat sizes become dramatically smaller leading to large increases in the surface treating pressure and hydraulic horse power (HHP) needed to generate a given net downhole pressure or injection rate.
To solve these limitations a revolutionary ball-activated fracturing system has been designed. This system behaves in similar fashion of activation to the traditional graduated ball seat frac sleeve in that the ball locks into place on the seat, but all the ball seats are the same size and retract, allowing the first ball to pass through all sleeves until it reaches the lowermost one. Similarly the next ball, which is the same size, lands on the next seat up and so on, allowing a virtually unlimited number of zones to be treated for either OH or cemented application. With this new system, there is no milling operation involved and the completion string maintains full drift inside diameter (ID) ready for production after stimulation operations have been completed.
In this paper the authors will describe in detail the operational mechanism of this new frac sleeve and present case studies of its use which illustrates the effect of this new technology in optimizing fracturing operations both in horsepower requirements and overall completion time and cost.
Professional Adaptation of Shift Workers in Oil and Gas Companies in the Arctic
Authors: Degteva G. , Simonova N. , Korneeva Ya. 
Published: September 2014

Abstract
Shift work in the Arctic has high requirements for the adaptation capabilities of workers. As a result of the shift workers professional activities four major types of adaptation strategies are formed. Determinants of their formation are the enviromental and personal resources in the context of the negative environment impact. The article the empirical adaptive startegy determinants of shift workers in Arctic analyze. It determined that shift workers of oil and gas production employ economical stereotyped adaptation strategy.
Well Placement and Reservoir Characterization Advancement in VTSM Field With New Multiple Boundary Delineation Technique
Authors: Lutfullin A. A. , Bregida A. A. , Tomchik M. V. , Kozlov V. N. , Shabalinskaya D. D. , Belyaev A. S. , Makhambetov A. S. , Shirshov A. Y. , Kim V. E. 
Published: September 2014

Abstract
The planned production attainment, and correspondingly economical feasibility of hydrocarbons production in BP16 suite in Vostochno-Tarkosalinskoe (VTSM) field directly depends on successful placement of horizontal section. The reservoir is highly heterogeneous and Well Placement is utilized not only to maximize the reservoir exposure, but also for supplementary exploration and understanding of the complex geological settings. The information obtained in the process of Well Placement is used with the purpose of detailed geological modeling, which defines further field development plan.
BP16 suite is represented by turbidites, which dictates application of modern logging while drilling (LWD) technologies and Well Placement techniques. However, all previously utilized technologies have reached their limit in their capability of formation description. More specifically, significant lateral variations make utilization of standard triple combo measurements (Gamma Ray, resistivity, density and neutron) insufficient. Multiple unconformably deposited layers and localized bodies create a considerable challenge for interpretation of azimuthal data (images) and pose some limitations on the inversion of directional electromagnetic (EM) measurements, obtained while drilling with the bed boundary mapping tool.
The new multiple boundary delineation technique was used while drilling to improve understanding of the layers extent, apparent dip and unconformable bedding. This technique is based on the stochastic inversion of extended set of deep EM measurements. The inversion resolves for formation electrical anisotropy, formation dip and allows for mapping of multiple boundaries in real time.
This paper is describing the experience of drilling horizontal wells in the VTSM field, where the multilayer inversion technology was used for Well Placement for the first time in Russia. The new technology was utilized not only for Well Placement, but also to obtain detailed information on geological settings around the wellbore. Geological modeling was later rectified based on this information and used for field development plan justification and formation pressure maintenance (FPM).
An Approach to Tight Paleokarst Zones Identification Based on Integrated Use of 3D Seismic Surveys, Core and Well-Log Data and Implication to Reservoir Quality
Authors: Skvortsov Anton , Kuleshov Vladislav , Ajiboye Moses , Agafonova Olga 
Published: September 2014

Abstract
Paleokarst system structures form an important type of carbonate reservoir, and are product of surface karst processes, further sediment compaction and diagenesis, all of which can contribute to the heterogeneity development and compartmentalization of a carbonate reservoir. One of the most important conditions is when the cave is filled by solid minerals such as anhydrite. Filling of the cave by Minerals and further compaction during area subsidence can destroy much of the original cavern porosity and significantly decrease the reservoir quality of the formation. For this reason, during the design stage of exploration and production drilling, it is necessary to pay attention on the pattern and distribution of paleokarst systems, make an assessment of their impact on reservoir properties which might affect the reservoir quality.
Digital Core Analysis for Flow Process Evaluation is Myth or Reality?
Authors: Shandrygin Alexander N. 
Published: September 2014

Abstract
Digital core analysis (DCA) based on 3D tomography of core samples is widely used for study and description a internal structure of rocks. At present time we can observe a lot of attempts to implement DCA for solving of special problems of multiphase and multicomponent fluids flow in porous media, especially for estimation of relative permeability and oil displacement efficiency by various agents for EOR tasks. But there are some restrictions for replacement of real special core analysis data (SCAL) by DCA results. This paper is devoted to the answer on the question: "can the DCA results reflect the real processes going in scale of core sample. A difference between results of flow parameters measured by DCA and SCAL are demonstrated, especially for value of efficiency displacement and phase permeability.
Use of Channel Fracturing Technology Increases Production and Reduces Risks in Horizontal Wellbore Completions - First Experience in Russia, South-Priobskoe Oil Field
Authors: Doctor Sergey A. , Tolmachev Alexey , Chebykin Nikolay , Yudin Alexey , Roukhlov Valery , Gromovenko Alexander , Mathur Anil 
Published: September 2014

Abstract
South-Priobskoe field is in process of active development for over 10 years at the moment. Main producing horizons are low-permeable sandstone formations AS10-AS12 of Neocomian age. Hydraulic fracturing in the vertical wells proved to be effective way to increase oil production and provided profitable development of the oil field for several years period. Many wells had commingled production from 2 or 3 layers; each of the layers was stimulated separately. However, recent shift of drilling and development activity towards edge areas of the field led to reduction in formation quality and seldom well intersects more than one productive interval nowadays.
Most effective way for such geological conditions is combination of horizontal well drilling development and multi-stage fracturing. This concept was successful applied worldwide for number of years and recently fulfill expectation at South Priobskoe field in Russia as well. Enhancement of oil production jointly with drainage scheme optimization allowed to decrease amount of wells and associated costs for infrastructure and well completion. Main weaknesses of this approach are increased screenout risks during fracturing operation and additional costs for horizontal wellbore cleanout in such a case.
Implementation of channel fracturing technology became the next step of production optimization and well completion cost reduction. New method allows increasing reliability of proppant placement while improving fracture conductivity. These results are obtained by pulsing proppant on surface in conjunction with specialized equipment and fibers. New technology was implemented in 110 vertical wells over Russia including positive experience of channel fracturing campaign in 3 wells in South-Priobskoe field.
This article describes Russia's first project of multistage stimulation (MSS) combined with channel fracturing technique applied in horizontal well. New approach allowed minimizing screenout risk, reducing completions costs and at the same time improving conductivity of hydraulic fractures. First production results showed increase in well productivity of over 15% compared to the neighboring horizontal wells stimulated by conventional MSS technique.
Hysteresis of Relative Permeabilities in Water-Gas Stimulation of Oil Reservoirs
Authors: Kokorev V. I. , Karpov V. B. , Darishchev V. I. , Akhmadeyshin I. A. , Bugaev K. A. , Shchekoldin K. A. , Dedechko V. A. , Polischuk A. M. , Shelyago E. V. , Yazynina I. V. 
Published: September 2014

Abstract
The paper presents the study of the water-gas stimulation process with alternate injection as applied to the core samples from the Vostochno-Perevalnoye oil field located in West Siberia. The test data analysis showed an increase of oil displacement efficiency due to gas displacement of oil and the dependance of relative permeabilities not only from the saturation history (hysteresis) but also from the number of water-gas stimulation cycles. The authors noted the hysteresis of relative permeabilities to be a significant factor requiring consideration when conducting experimental studies of relative permeabilities and computer modeling of the water-gas stimulation process.
Dynamic Modeling of Samotlor Field Using High Resolution Model Grids
Authors: Tolstolytkin D. V. , Borovkov E. V. , Rzaev I. A. , Bogachev K. Yu. 
Published: September 2014

Abstract
Effective field development planning for giant fields as big as Samotlor in Western Siberia faces a number of challenges. Samotlor field has almost 50 years of production history, and is known for its complex multi-reservoir geology, active gas cap, sophisticated waterflood program of giant proportions, and has more than 14 thousand wells. The field of such complexity and magnitude cannot be developed without a full-field hydrodynamic model covering the entire reservoir.
Historically, due to extreme complexity, only highly upscaled models have been used. These models were primarily used for calculation of the remaining reservoir energy, material balance analysis, gas cap migration, but never had enough spatial resolution to allow for simulations at the well level.
To make plans for infill drilling and various workovers, the most production units were relying on sector models, which did have necessary spatial resolution, but had obvious limitations in the areal coverage of the field. As a result, due to the differences in grid resolutions, the results obtained from history matching of sectors were rarely used for full-field model causing frequent inefficiencies and redundancies in simulation workflows.
In a course of planning work to develop the remaining oil reserves of Samatlor field, a new "unified model" concept has been developed. In this concept, one and the same model is being used both for global optimization of full-field model as well as for making decisions at the level of individual wells. To determine optimal grid resolution, models with 5, 40, 160 and more than 400 million active grid blocks were selected, and simulation results compared. For the first time, a new hydrodynamic model based on un-upscaled geological grid of AV1-5 reservoir group of Samotlor field was simulated. By taking into account the number of wells and the length of the production history, this is probably the most complex simulation of reservoir dynamics ever attempted in the oil&gas industry.