bluuebunny/crossref_metadata_2025_split huggingface dataset:
Thermal Simulation with Multilateral Wells
Authors: Bogachev K. , Tran H. , Milyutin S. , Sorokina M. 
Published: October 2016

Abstract
In this study we investigated full-field fine-scaled thermal reservoir models with multilateral wells that are independent of grid refinements and thus allow efficient optimization of well placements. This facilitated the production optimization and well interference study in thermal modeling framework. We observed that multilateral wells with multiple sidetracks enhanced the steam injection efficiency by enlarging steam chambers. We also examined the benefit of utilizing high performance computing (HPC) in multiple-node cluster environments. Results showed that excellent scalability was achieved with up to thousands of computing CPUs and total simulation time was reduced from weeks to hours. More importantly, the study confirmed that in thermal simulation coarser grid models overestimate steam chambers leading to overestimating total field production and reserves.
Integrated Modeling as a Tool for Evaluating the Effects of Well Production Rates and Surface Gathering System Performance on Development of Oil Rim
Authors: Ushmaev O. S. , Apasov R. T. , Chameyev I. L. , Mozhchil A. F. , Tkachuk A. V. , Kurochkin M.S. , Bolshakova A. A. , Vernus J. C. , Bayguzov R. A. , Maskaev P. S. 
Published: October 2016

Abstract
Efficient development of oil rims requires tools for making production forecasts to consider not only in situ processes, but also limitations of surface infrastructure.
This paper describes a case study of creating an integrated structural model of field X containing a block with 30 wells confined to an area of about 20 million m2.
Oil accumulations in this field are represented by marginal and underlying oil rims.
The basic concept of oil rim development in the field is re-injection of the produced associated gas back into the reservoir. Volumes of gas injected to maintain reservoir pressure affect oil production levels. Conversely, efficient oil well operation depends on associated gas production, including the gas breaking through from gas caps. With this development strategy, it is critical to consider the limitations of artificial lift systems, production gathering, and treatment systems to maximize economic performance of the project and to generate reliable oil, gas, and water production forecasts.
Integrated modeling is aimed at a detailed approach of predicting production levels by combining the reservoir, well, and surface gathering systems into a single generalized model. Such model should account for processes taking place in both the reservoir and surface gathering systems, as well as limitations such as gas and fluid velocities in well lifting and gathering network systems, design limitations of gas and oil treatment facilities, and pipeline loops and jumpers, with the final objective of improving the quality of decision-making.
The paper describes the basic steps of building an integrated model and the results of comparing production forecasts based on a conventional hydrodynamic model with those based on an integrated model. Calculations proved that well interventions are required for a more efficient field development to optimize production rates from the producing wells.
A Case Study of the Application of Geostatistical Inversion for Building a Three-Dimensional Geological Model of One of Uvat Reservoirs
Authors: Khamitullin I. M. , Novokreschin A. V. , Shilova Y. V. , Chernovets L. V. , Nikitin A. Yu. 
Published: October 2016

Abstract
This article describes the technology and results of geostatistical inversion for predicting reservoir properties of J3 reservoir in order to build a 3D geological model. It also describes the geological and geophysical data required to perform the geostatistical inversion including the quantitative and qualitative characteristics.
In the studied field, the main oil exploration target is associated with J3 reservoir. The complex structure of the reservoir is explained by the sharp facies variability common for continental depositional environments. Many equally possible realizations from the results of geostatistical inversion and their high resolution helped to reduce uncertainties and to refine the geological structure of the field. The reliability of the results is confirmed by a "blind" well which was drilled in the process of geostatistical inversion.
Advanced Modeling of a Field Pilot Program
Authors: Shigapova D. Yu. , Surnachev D.V. , Ryabov A.N. 
Published: October 2016

Abstract
In the manuscript the main idea is to tell about detailed 3D modeling as a good way to provide optimal plan of field pilot program (FPP) and to increase the value and reliability of the obtained information. It has to be noted that in this work will be detailed considered a process of the well test planning and design of horizontal wells, as one of the most important sources of information about the formation with limited time and / or production from the reservoir. Recommendations for modeling well tests using the geological and hydrodynamic model to account for the three-dimensional reservoir heterogeneity are provided.
It will be described about examples of work with an area of FPP at the field, which is situated in Arctic conditions. The authors believe that a similar approach can be greatly helpful in the planning of activities for offshore fields.
The main advantages of using detailed simulations during the planning and implementation of a field pilot program are:–Assessing the necessary and sufficient research in respect of the volume of fluid, the duration of holding time, revenue response, etc. taking into account the three-dimensional geological heterogeneity of the reservoir;–Keeping technology infrastructure constraints;–Formation of metrology hardware requirements;–The ability to quickly, in the process of implementation to adjust the plan and design activities and/or researches with the obtained information;–Communication and scalability well test results to the entire reservoir/field.
Geomechanics Based Completion Strategy Optimization for the Chemical Interaction Effect with Mechanical Properties
Authors: Smirnov N , Torres Martin Sigifredo , Valente Livan Blanco , Tadzhibayev Rustam , Vladimirovich Molodtsov Roman , Vitalievich Kuznetsov Igor , Pavlovich Khomenok Ivan 
Published: October 2016

Abstract
Wells with high strength carbonate reservoir formation generally practice open hole completion strategy. It allows to substantially reduce expenditures and risks associated with well construction. At the same time, borehole stability during well's exploitation depends on strength properties on the one hand, and stresses which rocks are withstanding during production on the other. In its turn stresses depend on many factors, related with geological aspects and are controlled by drawdown pressure applied to reservoir. Nowadays all main components for well stability can be identified with logging data, core information and software tools for modeling and computation.
In order to improve reservoir quality, quite often a near wellbore area is treated with different chemical agents and compositions. Unfortunately, a few people bear in mind, that after the chemical reaction rock might overcome significant changes as it weakens and deforms. This paper describes practical application of geomechanical modeling with Mechanical Earth Model construction [2] and reservoir stability evaluation of horizontal well section with the open hole completion before and after acid treatment with different depressions. [1].
In order to determine petrophysical and mechanical properties changes before and after acidizing, mechanical tests were conducted on the core samples from Bashkirian horizon. Results were used as a basis for justification and open hole completion optimization strategy.
Experience in 3D Geomechanical Modeling, Based on One of the West Siberia Oilfield
Authors: Ovcharenko Y. , Lukin S. , Tatur O. , Kalinin O. , Kolesnikov D. , Esipov S. , Zhukov V. , Demin V. , Volokitin Y. , Sednev A. , Podberezny M. 
Published: October 2016

Abstract
Work is devoted to construction 3D Geomechanics model for Achimov Formation for one of the West Siberia oilfield. The model is performed for monitoring and control field throughout the cycle of its life – start from drilling process (recommendation for optimization well trajectory and well design to exclude drilling risks) and during oilfield development (monitoring the development process to take account of changes in the stress state of the oilfield, its influence on the hydraulic fracture growth and hydrocarbon production processes). Oilfield, which are currently introduced in the development, characterize by increasingly complex geology and, consequently, require more sophisticated technological solutions for both the construction of wells and the development process, which involves the need to build complex 3D geological and geomechanical models.
As a result of the work was calculated current stress state on the field, taking into account the effects of faults. Special attention was paid to the process of mapping of faults and low-amplitude tectonic dislocation. For this purpose used inversion stress model, including simulation of deformations and displacements arising under the action of tectonic driver. This model allows to select the tectonic dislocation, the scale of which is significantly smaller than the resolution of seismic.
Based on the results of the verification of geomechanical model and sensitivity analysis to the source data, formulated the basic methodological approaches for building and testing models of geomechanical properties was done. During the work was made a forecast borehole stability for horizontal wells, create a map of faults, found the relationship between the faults parameters and their impact on the stress changes in the area of interest, assessed the impact of changes in reservoir pressure during field development on the stress orientation, predicted direction of hydraulic fracture and formed recommendations on hydraulic fracturing design taking into account possible variations in the stress state of the sector of modeling.
Experience of 20 Plus Stage Fracture Stimulation in Samotlorskoye Field
Authors: Kudrya Semen , Baydyukov Konstantin , Samoilov Mikhail 
Published: October 2016

Abstract
In 2009, OJSC "Samotlorneftegas" began performing two-stage fracture stimulations in newly drilled and sidetracked wells. The wells were treated zone-by-zone, with frac fleets doing two or more frac jobs. Slotted filter intervals were treated first. Then they were plugged off with bridge plugs or proppant for the next interval to treat. After two frac jobs, the bottom-holes were cleaned and the wells were started.
The success of the method consisted in an increased oil production at an early stage of production (around 40 tons per day from newly drilled wells) and in a slower decline in flow rates throughout the first year of production (around 35%) as compared to directional wells. There was only one disadvantage - a longer shut-in period (up to 60 days), which, with low formation pressures, can lead to a lower oil increment due to saturation of the formations with flush fluids.
In mid 2011, the multistage stimulation technologies did not find improvement for a number of reasons: No multistage fracturing equipment on the market. No such equipment was built in Russia and oil companies showed little interest in a large-scale application of purpose-built multistage fracturing completion systems;Lack of multistage fracturing experience;Significant geological and technological risks involved, when using these technologies to improve production to expected levels and enhance the cost effectiveness of these projects;Little experience in horizontal drilling with the drilling conditions being difficult to make large enough holes to accommodate multistage fracturing systems (MSFS). No effective annular isolation techniques.
In the first half of 2011, special ball-activated sleeves were delivered to the Russian market from abroad. However, OJSC "Samotlorneftegas" continued using an interesting multistage fracturing technique employing the use of burst port collars and cup-to-cup (C2C) tools.
The technology was being improved for 4 years. Owing to the improvement efforts, a unique 29-stage frac job was performed at the beginning of 2016.
Intensification of Oil Production Based on Invert-Emulsion with SiO2 Nanoparticles and Gelled Acid
Authors: Sergeev V. , Foundation Skolkovo , Imangaliyev B. , Ayupov R. 
Published: October 2016

Abstract
Results of Pashninsky oilfield wells operation monitoring after complex intensification of oil production (IOP) technology treatment are presented in article. The analysis of monitoring results of IOP technology's disadvantage was determined and ways of improvement of the technology were proposed. Based on results of laboratory research the most effective gelling agents for hydrochloric acid composition were proposed. Based on invert-emulsion (IES) new water-blocking solution with SiO2 nanoparticles content was developed. On results of interaction seven different gelling agents with hydrochloric acid composition by chemical laboratory tests have found that the most effective gelling agents are based on cocamide DEA (diethanolamide) agent that enable to reach viscosity by a factor of 3-8 to basic acid composition viscosity. Results of experiments on interactions of invert-emulsion solution with SiO2 nanoparticles content identified that nanoparticles presence into IES assist to structure stability and dynamic viscosity growth up to 800-1500 mPa·s.
Effect of Horizontal Wells Location on Steam Assisted Gravity Drainage Technology Efficiency
Authors: Amerkhanov Marat , Zaripov Azat , Shaikhutdinov Damir 
Published: October 2016

Abstract
Pilot extra-heavy oil production project in Tatarstan has demonstrated the effectiveness of steam stimulation technologies and horizontal drilling. The paper discusses approaches to increase the effectiveness of the steam-assisted gravity drainage (SAGD) process based on the results of in-depth study of geological aspects that contribute to well performance. Different scenarios of horizontal well placement have been analyzed. Criteria for optimal placement of horizontal wells in terms of geological conditions have been worked out. It has been found that on the one hand, the closer the horizontal well to the water-oil contact (WOC), the higher the final oil recovery factor, but, on the other hand, it takes a longer period to bring the well on to sustained production. The farther the horizontal well to WOC, the higher the effectiveness of the SAGD process, but the final oil recovery factor is lower, which is critical for heavy oil accumulations with relatively low OOIP in Tatarstan.
Mechanisms of Thermal-Pressure Induced Impact of Binary Mixture Reaction Near Wellbore
Authors: Vershinin V. , Fedorov K. , Lishchuk A. 
Published: October 2016

Abstract
The paper considers mechanisms of well production increase by applying thermal-gas-chemical impact or liquid explosive injection in a pay zone. We have introduced the computing model for thermal-gas-chemical impact process for thoroughly investigation of different contribution on well post production. Numerical calculations of thermal effects on formation heating of particular well during thermal-gas-chemical impact showed that utilized explosive slug simply cannot cause actual increase of production rates and observed effect duration. Then we analyzed the contribution of pay zone cleaning from asphaltene, tar and paraffin precipitations. And finally the mechanism of micro fractures network formation was discussed. Assessments of required explosive concentrations and microfracturing parameters in thermal-gas-chemical impact were performed.
Problems of Gas Condensate Field Production Solved by Novel Enlarged Block Simulator
Authors: Vershinin Vladimir Evgenyevich , Grigoryev Andrey Viktorovich , Fedorov Konstantin Mikhaylovich 
Published: October 2016

Abstract
The paper considers methods of gas and condensate production increase by choosing optimal well production parameters. The existing methods might become overcomplicated and require special optimization process for large amount.
To describe the well production parameters we have chosen the nodal model for the system: formation-well-flow line with specific closing relations. The optimization problem was formulated for the chosen nodal model but it requires a lot of calculations.
We have developed the solution algorithm where the task is discredited namely the subtasks that allow us to use dynamic programming and reduce calculations.
The solution of practical objective was taken as an example to maximize condensate production in the gas and condensate field.
Development Strategy Optimization and Application for Fractured-Vuggy Carbonate Gas Condensate Reservoirs
Authors: Yong Li , Baozhu Li , Jing Xia , Xuelei Zhang , Xingliang Deng , Zhicheng She , Zhiliang Liu 
Published: October 2016

Abstract
Naturally fractured-vuggy carbonate gas condensate reservoirs in China have some distinctive characteristics: deep buried depth, multi-scale fractures, vugs and caves developed, poor reservoir connectivity, high production decline rate and low estimated ultimate recovery. So how to properly develop this kind of reservoirs is a major challenge. This paper presents the study on development strategy optimization for fractured-vuggy carbonate gas condensate reservoirs in detail.
Based on the geological survey of palaeokarst outcrops and seismic interpretation, representative reservoir type patterns of fractured-vuggy carbonate gas condensate reservoirs can be determined. And combined geological study and dynamic characterization, different reservoir patterns can be identified and characterized. After that, simulation models of different reservoir patterns are built, in order to study the detailed development strategy on primary depletion and water flooding huff-and-puff. And optimal development strategies are applied into the TZ fractured-vuggy carbonate gas condensate reservoir in China.
Take TZ carbonate gas condensate reservoir in China for example. The mid-depth of TZ reservoir is 5500m with annual production decline rate higher than 25%. Through geological and dynamic characterization, six representative reservoir type patterns are identified and characterized. And more than half drilled patterns in TZ are isolated and developed in very limited volume, which only need one well to develop each pattern. Then reservoir simulation models of the six patterns are built to investigate the optimized development strategies. The results show vertical wells are optimum for four patterns and horizontal wells are optimum for two patterns. For isolated karst caves pattern, there are still lots of remaining condensate oil after primary depletion, so water injection huff-and-puff are studied for this pattern. The results are applied to TZ reservoir.
This paper offers a case study on development strategy optimization of different reservoir patterns for fractured-caved gas condensate carbonate reservoirs, and the understandings are successfully applied to TZ carbonate gas condensate reservoir. It also provides a methodology and an improved oil recovery reference case for engineers and geologists to develop other similar reservoirs.
Modern Integrated Approach to the Development of New Oil Fields
Authors: Vershinin Sergey A. , Elisenkov Pavel V. , Klimov Svyatoslav A. 
Published: October 2016

Abstract
It should be noted that during initial development period oil fields are usually developed by means of natural drive, without a reservoir pressure maintenance system. This is because infrastructure which allows organizing the injection of working substance doesn't exist - there is neither water injection system nor water injection pumping station. This results in reducing of reservoir pressure during exploitation.
To solve this problem application of a complex approach to the development and introduction of reservoir pressure maintenance system together with exploration the oil field in initial development period are offered.
This complex approach includes the use of a number of innovative technologies both in the organization reservoir pressure maintenance system (downhole and cluster injection, wellhead pumping station for maintenance reservoir pressure). In the oil production is dual completion and injection system with coaxial suspension.
The question of the possibility of applying this technology on prospective fields is considered. Targeted selection of candidate wells was made in accordance with the screening criteria. Technological and economic calculation of its efficiency is done. The prospects applications of a complex approach to the development of new o fields are revealed.
The Effect of Acid Treatments on the Bottom Zone of Clastic Reservoir Rocks of Perm Region
Authors: Plotnikov V. V. , Rehachev P. N. , Barkovsky N. N. , Mikhailov N. N. , Popov S. N. 
Published: October 2016

Abstract
The publication describes the aspects of laboratory analysis of acid influence on porosity and permeability and stress-strain behaviour of terrigenous reservoir rocks using the Perm Krai field as an example. A comprehensive laboratory study procedure for free volume and core sample testing in simulated reservoir conditions is represented. Certain test results for acid injection through a rock sample are given and acidizing impact on rock properties was assessed.
Analysis and Processing of the Results of Laboratory Experiments to Investigate Fracture Permeability Changes Under the Influence of Mechanochemical Effects of Water Injection into Carbonate Reservoir
Authors: Popov S. , Mikhailov N. , Plotnikov V. 
Published: October 2016

Abstract
The paper describes the results of laboratory experiments with fractured core samples. Fresh and distilled water was filtered through samples, and the samples were exposed to variable effective stresses. The experiments showed significant change of sample permeability caused by coupled mechanical and chemical (mechanochemical) effects. The results of studies were processed for determination of regularities in permeability variation in the process of water injection and the effective stress impact. As the result, the authors received the dependences of change of the fracture width on the fracture wall contact area, that can be used for prediction of change of the fractured reservoir permeability.